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Home My WebLink About192-102CAUTION: 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: Cancellation Request: PBU S-33 (PTD #192-102) 10-403 Request #322-599 Date:Thursday, September 14, 2023 1:05:29 PM Attachments:Appr Sundry_323-215_050123 S-33 MOC RWO.pdf Appr Sundry_323-080_032923 S-33 RWO.pdf James, FYI, I have noted this in the log. Grace From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, September 14, 2023 12:41 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Marshall Brown <Henry.Brown@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Cancellation Request: PBU S-33 (PTD #192-102) 10-403 Request #322-599 Hello, We request cancellation of two 10-403 Sundry Requests - #323-080 and #323-215(attached for reference). No reportable work was executed and the RWO has been cancelled. Please let me know if you have any questions. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Cell: (907)351-2459 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. RBDMS JSB 091423 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-33 Recomplete to Injector Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-102 50-029-22293-00-00 341J / 457B ADL 0028257 9510 Conductor Surface Intermediate Production Liner 9221 80 2922 8985 693 9428 20" 10-3/4" 7-5/8" 5-1/2" 9147 36 - 116 36 - 2958 33 - 9018 8815 - 9508 2439 36 - 116 36 - 2957 33 - 8774 8589 - 9219 9199 2480 5120 6280 None 5210 8180 7740 9044 - 9252 4-1/2" 12.6# 13cr80 30 - 88248797 - 8987 Structural 4-1/2" Baker S3 Packer 4-1/2" Baker SABL-3 Packer 8624, 8416 8763, 8542 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 4/28/2023 Current Pools: PRUDHOE OIL Proposed Pools: Schrader Bluff, Polaris STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-215 By Kayla Junke at 11:45 am, Apr 07, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.04.07 06:22:34 -08'00' Stan Golis (880) * See following page for conditions of approval. Recomplete to Injectorpj Convert Producer to an Injector in a New Pool SFD 4/10/2023 See following page for conditions of approval. 10-404 *BOPE test to 3000 psi. Annular to 2500 psi. *State to witness tag of TOC for Ivishak abandon no deeper than 8995' MD and pressure test to 2500 psi. *Approved for WINJ only. Gas injection will require cement isolation of all AOR offset wells from injection zone. *Hilcorp to provide monthly TIO plots of the identified AOR offset wells with risk of communication of injection fluids out of zone. *Hilcorp to perform PNL and temp. water-flow logs in all AOR offset wells uncemented across the SB within 6 months after injection commences and annually thereafter. *State to witness MITIA to 3500 psi after setting packer. *State to witness MITIA to 3500 psi within 7 days of stabilized injection. *Any indication of flow will require immediate shut in of injection and notification to AOGCC. *Variance to 20AAC25.402(b) is approved with these conditions. * See following page for conditions of approval SFD 5/1/2023 2439 DSR-4/13/23 CDW 04/25/2023 Prudhoe Oil: CO 341J; Polaris Oil: 484A SFD 4/10/2023 Schrader Bluff, Polaris MGR01MAY23GCW 05/01/23JLC 5/1/2023 05/01/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.01 14:48:04 -08'00' RBDMS JSB 050223 ConditionsofApprovalPTD192Ͳ102 PBUSͲ33Sundry323Ͳ215 1. BOPEtestto3000psi.Annularto2500psi. 2. StatetowitnesstagofTOCforIvishakabandonmentnodeeperthan8995’MDandpressure testto2500psi. 3. Approvedforwaterinjectiononly.Gasinjectionwillrequireverificationofcementisolationof allAORoffsetwells. 4. HilcorptoprovidemonthlyTIOplotsofthe20offsetwellswithnoCBLverifiedcementacross theSBsandswithin¼mileofthisinjector. 5. HilcorptoperformPNLandtemperaturelogsinall20offsetwellswithnoCBLverifiedcement acrosstheSBsandswithin¼mileofthisinjectorwithin6monthsafterinjectioncommences andannuallythereafter. 6. StatetowitnessinitialMITͲIAto3500psiafterinitialsetofinjectionpacker. 7. StatetowitnessMITͲIAto3500psiwithin7daysofstabilizedinjection. 8. AnyindicationofflowwillrequireimmediateshutinofinjectionandnotificationtoAOGCC. 9. Varianceto20AAC25.402(b)isapprovedwiththeaboveconditions. Recomplete to Schrader Well: S-33 Current PTD: 192-102 Well Name:S-33 API Number:50-029-22293-00 Current Status:Operable Estimated Start Date:4/28/23 Rig:Thunderbird 1 Sundry #?323-080, TBD Date Reg. Approval Rec’vd:3/29/23, TBD Regulatory Contact:Abbie Barker Permit to Drill Number:184-084 First Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Second Call Engineer:Claire Mayfield (970) 443-3631 (M) Current Bottom Hole Pressure:3319 psi @ 8800’ TVD 7.3 PPG | (10/5/2016 static) 7.6 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2439 psi (Based on 0.1 psi/ft. gas gradient) Min ID:3.725” XN at 8811’ MD Max Angle:26 Deg @ 8119’ MD 70 deg: N/A Formation Tops: Schrader (top of NA): 4933’ MD, 4929’ TVD Sag: 9045’ MD, 8799’ TVD Sadlerochit: 9311’ MD, 9040’ TVD MITs: MIT-T: 2575 psi on 9/1/2017 MIT-IA: 2472 psi on 9/1/2017 Objective: The Ivishak reservoir no longer remains economically viable at current fieldwide conditions/marginals. The Schrader interval for S-33 motherbore is in a perfect location to re-complete the well to uphole injection to support producer S-202 and M-200. A previous workover performed a USIT that confirmed TOC over the Schrader interval. A RWO is planned to recomplete to Schrader injection. This work will add 556 MSTBO reserves and an equivalent 1010 IOR at the producers. Well Summary: The drilling records for the well are limited. It is safe to say that by the time S-33 was drilled, the drilling program on S pad was fairly lined out. The production hole was drilled and set at 9018’ and cemented in place with 303 cu ft of Class G with additives. In 2005, bubbling at the conductor of S-33 was seen and the well was secured via DH plug and a passing negative test. In April 2008, a RWO was performed to address the conductor bubbling. After pulling the tubing, a USIT was pulled from 7000’ to surface. Verifying cement top at ~2700’ MD. x Top of cement: 2700’ MD x Top of Schrader @ 4933’ MD x Planned Top Perforation: 5051’ MD x Planned bottom Perforation: 5235’ MD Following the USIT, an RBP was set and pressure tested at 2732’ then the casing was cut @ 2625’. The 7-5/8” casing was pulled on the first attempt. On POOH, it was noted that the casing was in good condition however, the cut was too close to a collar looking up so a second cut was performed at 2637’. After polishing off the casing stub, a tieback string was run, pressure tested to 1000 psi then cemented in place with 132 bbls of ClassG. The EZ cementer and cement performed as expected. The cement was drilled out and the RBP was retrieved, and the completion was run and set as the well currently is configured. After the workover, there were several failed TIFLs that were eventually resolved with GLV changeouts. 192-102 SFD bubbling at the conductor o o recomplete to Schrader injection. T Recomplete to Schrader Well: S-33 Current PTD: 192-102 By 2010, the OA was seeing some re-pressurization though very minor, BP pumped 17 galls of ArcticSet I to resolve the issue. Since the OA re-pressurization issue was addressed, the well has seen minor slickline GLV work. Ivishak Abandonment Plug: The proposed Ivishak abandonment plug will be set above the top of Sag @ 9030’ MD. This is within 50’ MD above the top existing perforation, below the production casing shoe and should be in good cement of the 5- 1/2” liner. After setting the inflatable plug, we will dump bail sand to protect it for future retrieval prior to dumping 25’ of cement on top of the sand. The planned top of cement is at 8995’ inside the production liner/casing. We should have good cement in the 5-1/2” liner and expect good cement quality at the production casing shoe. With a cement top at 8995’, we will have good circumferential coverage from 8995’ – 9020’. Area of Review – PBU S-33 (PTD # 192-102) Prior to the conversion of well S-33 from Ivishak Injector to Schrader Injector, an Area of Review (AOR) was conducted. This AOR found 23 wells within ¼ mile of S-16’s entry point into the Schrader Formation. See attached table Area of Review S-33 for annulus integrity and zonal isolation of all wells within the AOR. 5 wells within the ¼ mile radius do not have cement across the Schrader interval when calculated volumetrically. These wells are S-06, S-08, S-10, S-20 and S-24 (see table below). Hilcorp requests a variance from 20 AAC 25.402 (b) due to not having adequate cementing data across the confining zone for wells within the ¼ mile radius of an injection well under 20 AAC25.402(h). The assurance that the injection zone is isolated is based on the following: 1. Hilcorp provides monthly TIO plots of the five wells. If out of zone injection occurs alongside the un- cemented portion of the casings on these wells, it may show up in the OA pressure-plots as an anomaly. 2. Hilcorp performs PNL & Temperature Water-Flow logs in the five wells across the Schrader interval within 6 months after injection commences, and annually thereafter. 3. Alternatively, if Hilcorp performs a CBL of the Production Casing on any of these five wells and submit to AOGCC for review. If sufficient cement isolation exists across the Schrader for any of the five wells then that well would not be subject to the requirements above. ** See 10-403 Sundry #323-080 for AOGCC approval of variance and requirements per CDW & MGR. ** Sundry Procedure (Approval Required to Proceed) Pre-Rig 1. Obtain updated pressure tests on WH seals Slickline with fullbore assist 1. Drift 2. B&F tubing 3. Pull caliper from tubing tail to surface a. Looking to evaluate tubing re-usability b. Tubing is 2008 install, we will save as much as possible 4. Set plug in X nipple @ 8658’ 20 S-06, S-08, S-10, S-20 and S-24 (see table below). 20 variance from 20 AAC 25.402 (b) d t may s 20 f S-16’s 5 wells within the ¼ mile radius do not have cement across the Schrader interval w 20 20 20 offset wells within 1/4 mile do not have CBL verified cement across the Schrader Bluff interval. Recomplete to Schrader Well: S-33 Current PTD: 192-102 5. Dummy GLVs 6. Pull St1 GLV for circ’ing in KWF 7. Load hole with 2% KCl + Freeze protect a. Total T+IA volume to St#1: 353 bbls b. Freeze protect volume to 2500’: 104 bbls 8. Obtain 3500 psi MIT-IA 9. MIT-T to 3500 psi 10. Pull plug in X Eline 1. Spot E-Line unit to well, RU and PT. 2. MU, RIH and set IBP in @ 9030’ a. Top perf is at the top of Sag, confirm top perf with OE/geo prior to setting plug, the plug will be set within 50’ of top perf. 3. Dump bail 10’ of sand on IBP 4. Dump bail minimum of 25’ of cement on IBP 5. After dump bailing cement, state witness the tag of TOC. 6. Pressure test cement plug to 2500 psi, state witness cement plug pressure test 7. MU tubing cutter and RIH and correlate. 8. Pick up and cut tubing at 8608’ 9. ~4’ into pup on top of packer a. Correlate to Tubing Tally dated 4/22/2008. b. RDMO Eline. Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. Most recent static was obtained in 2016. This value should be accurate and ~2% KCl may be used as KWF. 1. Check well pressures, re-kill well as needed 2. RD well house and flowlines. Clear and level area around well. 3. Set BPV w/insert (TWC) and test. ND Tree and THA. 4. NU BOPE configured top down: Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird 1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/2% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”and 3-1/2”test joint. Recomplete to Schrader Well: S-33 Current PTD: 192-102 e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~8608' of 4-1/2” 12.6# tubing weighs ~ 95klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut, discuss with OE. 6. POOH and lay down the 4-1/2” tubing. a. Save tubing if possible, pre-rig caliper will inform joints to be discarded b. If any galling at connections is seen, discard these joints as well 7. RU Eline and pressure test 8. Perforate the following intervals per tie in log attached. Confirm tie in with geologist a. OA sand: 5051’ – 5072’ MD (21’ perfs) b. OBa sand: 5086’ – 5102’ MD (15’ perfs) c. OBb sand: 5120’ – 5134’ MD (14’ perfs) d. OBc sand: 5165’ – 5183’ MD (18’ perfs) e. OBd sand: 5213’ – 5235’ MD (22’ perfs) f. Guns: 2.875” MaxForce, 175 MaxForce HMX or similar i. 38.6 penetration, 0.37” EHD g. Confirm shot depths with Geo: Kevin Eastham: 907-777-8316 i. Call Brodie if Kevin unavailable 9. PU new/used 13Cr80 completion and run per S-33 Proposed Schrader Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~5230’ c. Ensure RHC plug body pre-installed in lowermost X profile 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Drop ball and rod and hydraulically set the packers per manufacturer’s setting procedure a. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed – provide 24 notice to AOGCC) 12. Shear circ valve in GLM and circ freeze protect. 13. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 14. RDMO TB Rig and ancillary equipment. Move to next well location. 15. RU crane. ND BOPE. 16. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 17. Pull BPV with TWC insert. 18. Replace wellhouse and gauge(s) if removed. Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±5230’ MD Recomplete to Schrader Well: S-33 Current PTD: 192-102 3. Dummy GLV above top packer 4. Install WFRVs per below: WFM #Approx Depth, MD Injection Zone WFRV Valved Rate, bwpd 9 5051’OA 500 8 5072’OA 0 7 5086’Oba 500 6 5102’Oba 0 5 5120’OBb Gutted w/ check valve 4 5134’OBb Gutted w/ check valve 3 5165’OBc Gutted w/ check valve 2 5183’OBc Gutted w/ check valve 1 5213’OBd Gutted w/ check valve X-nipple Tubing tail OBd Gutted w/ check valve 5. RDMO Operations 6. Obtain AOGCC witnessed SVS test within 5 days of putting well online. 7. AOGCC to witness MIT-IA within 7 days of stabilized injection. 24 hour notice. Attachments: 1. As Built Wellbore Schematic 2. Proposed Wellbore Schematic 3. Nordic 3 BOP Stack 4. USIT Log 5. Tubing Tally 6. Tie In Log 7. AOR 8. Sundry Change Form Recomplete to Schrader Well: S-33 Current PTD: 192-102 Current WBD: Recomplete to Schrader Well: S-33 Current PTD: 192-102 Proposed Schrader Injector WBD: 4-1/2" x 9-5/8" Scoop Guide 4-1/2" x 9-5/8" Scoop Guide 4-1/2" x 9-5/8" Scoop Guide 4-1/2" x 9-5/8" Scoop Guide 4-1/2" x 9-5/8" Scoop Guide 4-1/2" x 9-5/8" Scoop Guide Retrievable expandable bridgeplug @ 9030' ~10' of sand on plug minimum 25' of dump bailed cement on sand TOC @ 8995' Ivishak perfs:9044' - 9252' Isolated by plug and cement OBd Perfs: 5213' - 5235' OBc Perfs: 5165' - 5183' OA Perfs: 5051' - 5072' OBa Perfs: 5086' - 5102' OBb Perfs: 5120' - 5134' A production packer will be installed between each perforation interval Between each production packer, we will install 2 waterflood injection mandrels and a single X- nipple to assist with interventions/zonal isolation. Top Packer @ ~5000' MD Bottom Packer @ ~5190' MD Tubing tail/WLEG: @ ~5230' 2x 3-1/2" x 1.5" WFRMs per injection zone 4-1/2" x 7-5/8" Scoop Guide @ 8620' 3-1/2" L80 tbg tail @ ~5230' Recomplete to Schrader Well: S-33 Current PTD: 192-102 Thunderbird Rig 1 BOP Schematic Recomplete to Schrader Well: S-33 Current PTD: 192-102 7-5/8” USIT log showing top of cement: Recomplete to Schrader Well: S-33 Current PTD: 192-102 Tubing Tally: Recomplete to Schrader Well: S-33 Current PTD: 192-102 Tie in Log: Recomplete to Schrader Well: S-33 Current PTD: 192-102 AOR Map: Recomplete to Schrader Well: S-33 Current PTD: 192-102 AOR Summary Table: VV V VL VVLVV*VVVVLV*V VVV*V*VV* Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 6, 2023Subject: Changes to Approved Sundry Procedure for Well S-33Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date JLC 3/29/2023 RBDMS JSB 033023 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, September 3, 2017 3:05 PM To: AK, GWO Well Integrity Engineer;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL; AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer S-33 (PTD# 1921020)Well barriers restored All, Producer S-33 (PTD#1921020)was made not operable on 7/10/17 for failing a warm TIFL post orifice gas lift valve change out. On 9/1/17 slickline dummied off all gas lift mandrels, set a tubing tail plug, and performed a passing MIT-T to 2,575psi and passing MIT-IA to 2,472psi. The well now has two competent barriers and is reclassified as Operable. Please mind fluid pack annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer - Office: 907-659-8110 SCANNED ` t P 1 4 2 017, Cell: 907-341-9068 WO —weft....wast From: AK, GWO Well In -: Engineer Sent: Monday, July 10, 2017 2:.. To: AK, OPS GC2 Facility OTL; AK, OP t Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS ' - PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells •: Engr; AK, RES GPB West Wells Opt Engr; Bergene, Matthew; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, . 0 Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; De , David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katheri ternicki, Oliver R; Worthington, Aras J; 'chris.wallace@alaska.gov' Subject: NOT OPERABLE: Producer S-33 (PTD# 1921020) Failed Warm TIFL Post GLV Change t. All, 0 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,July 10, 2017 2:06 PM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S; AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL; AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer S-33 (PTD# 1921020) Failed Warm TIFL Post GLV Change Out. All, Gas lifted Producer S-33 (PTD#1921020)was made under evaluation on 05/16/2017 for exceeding NOL on the inner annulus and failing a subsequent TIFL. Slickline performed a gas lift change out on 06/10/17, but could not pop the well for a warm TIFL due to a pad shutdown,the UE clock was rolled for an additional 28 days. On 07/9/17 DHD performed a failing warm TIFL indicating the TxIA communication has not been mitigated with the gas lift change out. The well is now reclassified as Not Operable and will remain shut in until barriers can be restored. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: MIT-T, CMIT-TxIA 3. Slickline: (contingent if MITs pass) Pull TTP 4. Production Engineer: Evaluate Plan Forward if MITs fail Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED 1\(J1 0 8 2.0?"/ wo From: AK, GWO Iv itegrity Engineer Sent: Monday, June 12, 21 •21 PM To: AK, GWO Well Integrity Enginee , , OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lea., • OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt n• • K, OPS WELL PAD S; Bergene, Matthew; Regg, James B (DOA) 1- • S Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, October 09, 2016 8:06 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras Subject: OPERABLE: Producer S-33 (PTD#1921020) Passed Tubing Integrity Fluid Level Test All, Producer S-33 (PTD#1921020) passed a Tubing Integrity Fluid Level test on 10/09/16,following gas lift valve work.The passing test confirms two competent well barrier envelopes.The well is reclassified as Operable. Work Completed: 1. Downhole Diagnostics: Cold TIFL—Failed 09/20/16 2. Slickline: Change out orifice gas lift valve—Completed 10/06/16 3. Downhole Diagnostics:Warm TIFL—Passed 10/09/16 Thanks, Adrienne McVey SCANNED FEB 2 7 2617 Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com Fr. •': AK, GWO SUPT Well Integrity Sent: •-sday, September 21, 2016 3:25 PM To: AK, GWO SI' i ell Integrity; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, 0' • Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, 0' ELL PAD S; Bergene, Matthew; Regg, James B (DOA) (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, , 4 Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Munk, Corey; Pettus, Whitney; Sternicki, Oliver R; Worthingt. ras J; AK, GWO DHD Well Integrity; AK, GWO Well Integrity Well Information; Bergene, Matthew Subject: UNDER EVALUATION: Producer S-33 (PTD#19211' Possible Tubing by Inner Annulus Communication All, Producer S-33 (PTD#1921020)exceeded inner annulus MOASP on 9/18/16. A TIFL • d on 9/20/16 indicating possible anomalous tubing by inner annulus communication. The well is now reclassified as Under aluation to further diagnostics and repair or secure within 28 days. 1 f)/3 Pm 19z10zO Regg, James B (DOA) Sent: AK, D&C We21n2013y1 $Coordinator(AKDCWellIntegrityCoordinator @bp.com] ley 6fri/, To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS I Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Regg, James B (DOA); Schwartz, Guy L (DOA); Weiss, Troy D; Glasheen, Brian P; AK, OPS WELL PAD S Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: Producer S-33(PTD# 1921020) Unable to run Surface Diagnostics due to Maintenance All, Producer S-33 (PTD# 1921020) has been Under Evaluation due to breaking MOASP on the IA during a pad shut down. However, due to maintenance the well will not.be able to be brought online within the 28 day clock.At this time the well has been reclassified as Not Operable until further diagnostics can be performed. Plan Forward 1. Operations: Bring well online once pad work is complete 2. DHD: Perform a warm TIFL Thank You, Laurie Climer (,4lternatc:Jack f)ishroi,l SCANNED FEB 2 0 2014 BP Alaska - Well Integrity Coordinator 1� ,g& ormt.o�, WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, June 13, 2013 10:25 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 We pad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; 'jim.,-gg @alaska.gov'; 'Schwartz, Guy L (DOA)'; Weiss, Troy D; Glasheen, Brian P; AK, OPS WELL PAD S Cc: 'AK, D&C DHD Well Integrity Engineer'; AK, D&C Projects ell Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer S-33(PTD# 19211,0) failed TIFL All, Producer S-33 (PTD# 1921020)was found to have su ained IA pressure above MOASP on 06/10/13 during a plant shut down;TBG/IA/OA= 250/2260/200 psi.A subseque,t TIFL on 06/13/13 failed.The well has been reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Slickline: change out orifice gas lift alve 1 Pros-g; Regg; James B (DOA) ti'z lcu, From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] I Sent: Thursday, June 13, 2013 10:25 PM �91'14113 To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Regg, James B (DOA); Schwartz, Guy L (DOA); Weiss, Troy D; Glasheen, Brian P; AK, OPS WELL PAD S Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer S-33(PTD# 1921020) failed TIFL Attachments: S-33 TIO 6-13-2013.docx; S-33 Wellbore Schematic.pdf All, Producer S-33 (PTD# 1921020) was found to have sustained IA pressure above MOASP on 06/10/13 during a plant shut down;TBG/IA/OA= 250/2260/200 psi. A subsequent TIFL on 06/13/13 failed.The well has been reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Slickline: change out orifice gas lift valve 2. DHD: Re-TIFL well Copies of the wellbore schematic and TIO plot have been included for reference. Please call with any questions. Regards, SCANNED FEB 2 02014 Laurie Climer (Alternate-Jack/)rot,') BP Alaska - Well Integrity Coordinator 16,1 w 0/gdniza1=on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com 1 ff� +l I a H 3 � I H i N O � C a a 0 0 CO O N as N N CO CO M TREE= Mc EV OY ' WELLHEAD= FMC SA, NOTES:***CHROME TBG&LNR*** ACTUATOR= OTIS S-33 KB.ELEV= 69' BF ELEV 37' , —Max KOP 5966' r'! '♦. 2098° H4-1/2"HES X NIP, ID=3.813" Angle= 26'@ 8119' 1i ! Datum MD= 9123' �l1� �• J—{ Datum TV D= 8800'SS Pe ;+� 2582' 7-5/8"HES CEMENTER 20"CONDUCTOR,91.54,H-40, ID=19.124" 110' 2590' J--I7-5/8"BKR EXTERNAL CSG PKR I 7-5/8"CSG,29.74,L-80 TCII, ID=6.875" H 2643' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.54,NT-80 BTC, ID=9.953" -I 2958' 5 3228 3326 5 KBG2 DOME BK 16 09/14/09 4 4810 4807 3 KBG2 DOME BK 16 09/14/09 3 6202 6190 14 KGB2 DOME BK 16 09/14/09 2 7486 7383 24 KGB2 DOME BK 16 09/14/09 1 8515 8317_ 25 _ KGB2 SO BK 20 09/14/09 Minimum ID = 3.725" @ 8811' 4-1/2" PARKER SWN NIPPLE 8593' I-I4-1/2"HES X NIP, ID=3.813" I �' kat 8624' I-17-5/8"X 4-1/2"BKR S-3 PKR,ID=3.87" I 8658' H4-1/2"HES X NIP, ID=3.813" I 4-1/2"TBG, 12.64, 13CR-80 VAM TOP, -I 8717' I .0152 pf, ID=3.958" 8732' H7-5/8"UNIQUE OVERSHOT 4-1/2"TBG STUB(03/12/08) —I 8728' X ►'l 8763' H7-5/8"x 4-1/2"BKR PERM PKR, ID=3.92"I ' 8793' I-I4-1/2"PARKER SWS NIP, ID=3.813" I 8811' 114-1/2'PARKER SWN NIP, ID=3.725" I TOP OF 5-1/2"LNR -{ 8815' I Id 4-1/2"TBG, 12.6#,13CR-80 NSCT, —I 8824' I / I 8824' H4-1/2"W/LEG, ID=3.958" I .0152 pf, ID=3.958" - 8826' H ELMD TT LOGGED 12/31/92 I 7-5/8"CSG,29.7#,NT95HS NSCC. ID=6.875" H 9018' PERFORATION SUMMARY I REF LOG:BHCS ON 10/19/92 ANGLE AT TOP PERF:25°@ 9044' Note: Refer to Production DB for historical perf data 1 NK 4-BLADES FROM SWS, FFISH ISH-JUNK E SPINNER SIZE SPF INTERVAL Opn/Sqz DATE I 9199 3-3/8" 4 9044-9084 0 07/03/93 3-3/8" 6 9166-9252 0 01/06/92 PBTD H 9428' '��'',,� 1!!!1!1!!li� 5-1/2"LNR, 17#, 13CR FL4S, .0232 bpf, ID=4.892" -I 9508' �•!!••••••1.!''' DATE , BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 10/29/92 N28E ORIGINAL COMPLETION 10/04/09 RPC/SV PULL PXN(09/15/09) WELL: S-33 04/22/08 D16 RWO PERMIT No:°'1921020 11/17/08 AW/JMD DRLG DRAFT CORRECTIONS API No: 50-029-22293-00 12/15/08` PJC DRLG DRAFT CORRECTIONS Sec.35,T12N, R12E, 1639 FNL&1487 FWL 08/24/09 GJF/PJC GLV C/O&SET PXN(08/01-06/09) 10/04/09 CJN/SV GLV C/O(09/14/09) 1 BP Exploration(Alaska) Producers with sustained casing pressu on IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, January 12, 2011 10:42 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: King, Whitney; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead Subject: Producers with sustained casing pressure on IA and OA due to proration Jim /Tom /Guy, The following producers were found to have sustained casing pressure on the IA during the proration January 10 -12. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 03 -28 (PTD #1840720) 12 -15 (PTD #1830320) 12 -36 (PTD #1951580) AdiNtti ».iA 2 2O1 S - 'TD #192 • • Z -30A (PTD #2032190) The following producers was found to have sustained casing pressure on the OA during the proration January 10 -12. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 03 -08 (PTD #1760730) 03 -28 (PTD #1840720) Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/13/2011 ~ ~ bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 ~" Anchorage, Alaska 99519-6612 5 "~ £` June 25, 2009 -~ ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annuius. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~; n .,~ ~~~; . ~~;l~'~9~~'~ ~ui.. ~; Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Spad \ ..~r~ nAea fil25/2009 W ell Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cemen[ top off date Cortosion inhibitor Cortosion inhibitod sealant date ft bbls ft na al S-018 7952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1947090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5l20/2009 S04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/'L009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-08B 2010520 0 NA 0 NA 0.95 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/37/2009 S-t0A 1971230 0.5 NA 0.5 NA 3.4 5/31I2009 5-116 1990530 025 NA 025 NA 7.7 5/27/2009 S12A 1851930 0.25 NA 0.25 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-~5 1840770 025 NA 0.25 NA 3 6/2/2009 S-t7C 2020070 0.25 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5119/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 025 NA 1.7 5/25/2009 5-246 2037630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960720 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31l2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5l26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5l31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 1.25 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 025 NA 702 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5l30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/29/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 1.25 NA 125 NA 71.9 5/29/2009 5-102L7 2031560 1.25 NA 1.25 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 SI20/2009 5-106 2010120 7625 NA 1625 NA t74.3 6/2/2009 5-107 20i1130 225 NA 2.25 NA 28.9 5/)8/2009 S-~08 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-t09 2022450 2 NA 2 NA 27.3 5/30/2009 S-110 2011290 11.75 NA 71.75 NA 98.6 5/30/2009 S-t 7 ~ 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.7 5/18/2009 S-114A 2021980 125 NA 125 NA tOZ 5/30I2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-778 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-12t 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-724 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 7.25 NA 15.3 &1/2009 5-200 1972390 125 NA 725 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-273A 2042130 2 NA 2 NA 13.6 5/29l2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2W9 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 > STATE OF ALASKA~~~G~ ~D~ ~ ~' ~~ "` A~ OIL AND GAS CONSERVATION COMICIISSION MAY ~ ~ 208 REPORT OF SUNDRY WELL OPERATIONSi~~s~~ ~~~ ~ Gas Cons. Commission 1. Operations Performed: Cage ^ Abandon ®Repair Well- ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Welf ~~l / L1Q Alter Casing , f-l ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development~ ^ Exploratory 192-102 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22293-00.00 ' 7. KB Elevation (ft): 69, - 9. Well Name and Number: PBU S-33 8. Property Designation: 10. Field /Pool(s): ADL 028257 _ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9510 - feet true vertical 9221 ~ feet Plugs (measured) None Effective depth: measured 9430 feet Junk (measured) 9199 true vertical 9148 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 76' 76' 1490 470 Surface 2922' 10-3/4" 2958' 2957' 5210 2480 Intermediate 8981' 7-5/8" 9018' 8774' 8180 5120 Production Liner 693' 5-1/2" 8815' - 9508' 8589' - 9219' 7740 6280 ~'~~I~~~ JUN ~ ~ 200 Perforation Depth MD (ft): 9044' - 9252' Perforation Depth TVD (ft): 8797' - 8987' 4-1/2", 12.6# 13Cr80 8824' Tubing Size {size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2" Baker S-3 Packer 8624' 7-5/8" x 4-1/2" Baker'SABL-3' packer 8763' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 8728'. Cut and pull 7-5/8" casing from 2637'. Run 7-5/8" (29.7#, L-80, TC-11) tieback to surface. Cement w/ 132 bbls Class 'G' w/ Gas-Blok 741 cu ft / 639 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 80 350 Subsequent to operation: 656 996 1473 600 200 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact Paul Chan, 564-5254 308-082 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Sign re Phone 564-4750 Dat Z-O Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 R I ~ I N A L sub Original Only c~ ~S - p~ TREE _` 4-1/16" 5M McEVOY WELLHEAD= FMC ACTUATOR = OTIS KB. ELEV - 69' BF. ELEV _ 37 KOP = 5966' Max Angle = 26 @ 8119' Datum MD = 9123' Datum TV D = 8800' SS S NOTES: ***CHROME TBG &LNR*"* S-33 u rfa Ce TOP OF CEMENT In 7-518"x 10-3;4" 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" I~ 2958' 4-112" 12.6#, 13Cr Vam Top, 0.0152 bpf, ID = 3.958" TOP OF 5-1 /2" LNR ~-i 4-1/2" TBG, 12.6#, NSCT 13CR, 0.0152 bpf, ID = 3.958" 8707` I 8815' 8824' 1398` -14-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 3328 3326 5 KBG2 DOME BK 16 05/15/08 4 4810 4807 3 KBG2 SO BK 20 04/29/08 3 6202 6190 14 KBG2 DN1Y BK 0 04/22/08 2 7486 7383 0 KBG2 DMY BK 0 04!22/08 1 8515 8317 25 KBG2 DMY BK 0 04/22/08 $593' 4-1I2" HES 'X' Nli~r LE, ID = 3.813° 8624' Baker S-3 Pkr, ID = 3.87" 865$' 4-1,'2" HES 'X' NIPPLE, ID = 3.813" $717' Uniiq. MachlneC7vershot 4-112x7-5/8 8763' -~ 7-5/8" x 4-1/2" BKR PERM PKR, ID = 8793' 4-1/2" PARKER SWS NIP, ID = 3.813" 8811' 4-1/2' PARKER SWN NIP, ID = 3.725" 8826' ~ ELMD TT LOGGED 12/31/92 17-5/8" CSG, 29.7#, L-80, 0.0459 bpf, ID = 6.875" I PERFORATION SUMMARY REF LOG: BHCS ON 10/19/92 ANGLE AT TOP PERF: 25 @ 9044' Note: Refer to Production DB for historical serf data SIZE SPF INTERVAL Opn/Sqz 3-3/8" 3-3/8" 4 6 9044-9084 9166-9252 C C 07/03/93 01/06/92 PBTD I~ 9430' +5-1/2" LNR, 17#, 13CR, FL4S, 0.0232 bpf, ID = 4.892" ~--~ 9510' 9199` I'-I JUNK 4-BLADES FROM SWS, FULLBORE SPINNER DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/92 ORIGINAL COMPLETION 04/22/08 D16 RWO 05f15/O8 DAViTLH GLV CIO (4x'29 & 5115) PRUDHOE BAY UNff WELL: S-33 PERMff No: 92-1020 API No: 50-029-22293-00 Sec. 35, T12N, T12E BP Exploration (Alaska) Digital Well File Well: S-33 Well History Well Date Summary S-33 3/4/2008 T/I/O =SSV/280/50. Temp = SL_Monitor fluid in cellar (SC leak). Removed -1 cup fluid from 1/2 drum. S-33 3/4/2008 ***WELL S/I ON ARRIVAL*** (pre RWO) PULL PRONG W/ 3.60" B.GUIDE, 2 1/2" JD @ 8778' SLM PULL PXN PLUG BODY @ 8785' SLM (BACK W/ALL PKG ) **WELL LEFT SHUT IN /TURNED OVER TO PAD OP** S-33 3/6/2008 T/I/O=SSV/280/50. Temp=Sl. Monitor fluid in cellar (SC leak). removed 2 drops of fluid from half drum. S-33 3/12/2008 T/I/O = 390/320/60 Assist E-Line, CMIT TxIA PASSED to 3500 psi (RWO prep) E-line set fasdrill.. Pumped 11 bbls of crude down IA to achieve test pressure. T/IA lost 40/60 psi 1st 15 mins, T/IA lost 30/20 psi 2nd 15 mins for a total loss of 70/80 psi in 30 mins. Bled pressures. Final WHP's = 250/340/20. ANNULUS CASING VALVES-TAGGED AND LEFT OPEN ON DEPARTURE. S-33 3/12/2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL T/ I/ O = 400 / 350 / 100. ELINE RU RIH AND SET HALLIBURTON FAS DRILL BRIDGE PLUG AT 8817'. _ LRS PT'ED PLUG TO 3500 PSI -PASSED, BLED BACK TO 100 PSI. RIH WITH 3.65" POWERCUTTER TO CUT TBG AT 8728 FT. GOOD SURFACE INDICATION THAT JET CUTTER SHOT. T/I/O 150/140/0 ***JOB CONTINUED ON 13-MAR-2008*** S-33 3/13/2008 *** CONTINUED FROM 12-MAR-2008*** CONTINUE ELINE RIGDOWN POST- TUBING CUT. WELL LEFT SHUT-IN. FINAL T/I/O 150/140/0. ***JOB COMPLETE*** S-33 3/18/2008 T/I/0=100/100/80, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into tubing hanger test void to check pressure (0 psi). Functioned LDS all moved freely, torqued to 500 ft/Ibs. Pumped through void until clean fluid returns were achieved. Pressured void to 5000 psi for 30 min, lost 0 psi in 15 min, lost 0 psi in second 15 min (Pass). Bled void to 0 psi. PPPOT-IC: Stung into casing hanger test void to check pressure (0 psi). Functioned LDS all moved freely, torqued to 500 fUlbs. Pumped through void until clean fluid returns were achieved. Pressured void to 3500 psi for 30 min, lost 150 psi in 15 min, lost 50 psi in second 15 min (Pass). Bled void to 0 psi. S-33 3/29/2008 T/I/0=0/0/50 temp=s/i Circ. Out; Freeze Protect (RWO Prep) Pump 5 bbls neat meth, 563 bbls 1 % kcl, 91 bbls diesel down tbg returns up IA & down flowline. U-tube diesel to freeze protect TxIA. Freeze protect flowline w/5 bbls meth, 29 bbls crude, & 10 bbls diesel. **Annulus valves tagged & left open to gauges, well left s/i & flagged & tagged.*** FWHP's=0/0/0 S-33 4/5/2008 T/I/O=SSV/VAC/45. Temp=Sl. Monitor fluid in cellar (SC leak). (SAP increased 45 psi since 03/29/08. removed 1.75 aal of fluid from half drum. Fluid is dripping into the half drum C«~ 1 drip per 3 sec. S-33 4/9/2008 T/I/0= SSV/Vac/40. Temp= SI. Monitor fluid in cellar (SC leak). OAP decreased 5 psi in 4 days. Removed 4 cups of fluid from half drum. Fluid was not dripping in to half drum during monitor. S-33 4/11/2008 T/I/O=SSV/Vac/50. Temp=Sl. Bleed OA to psi (pre-rig). OA FL (~ surface. Bled OAP to bleed tank from 50 psi to 0 psi in 3 hr. Monitored 30 min, OAP increased 5 psi. Removed 2 pints of fluid from half drum. Final WHPs=SSV/Vac/5. S-33 4/12/2008 T/I/O = 0/0/0 Set 4 1/16" CIW H BPV S-33 4/13/2008 T/I/O =VAC/0/0 Pulled 4 1/16" CIW H BPV S-33 4/14/2008 T/I/O = 0/0/0 Pulled 4 1/16" CIW H TWC Post BOPE test. Doyon 16 S-33 4/20/2008 Tool inspection charges S-33 4/22/2008 T/I/0=75/0/O;Pull 4-1/16" CIW "H" TWC thru tree for DOYON 16 Completion; 1-2' ext. used, tagged C~3 96". ***Complete*** (Best/Wortham) S-33 4/23/2008 Ui/o=0/0/0. Set 4 1/16"H" bpv @_:102" 1x2' ext used. No problems Doyon 16 Completion.,.... S-33 4/28/2008 T/I/0=0/0/0; Pull 4-1/16" CIW "H" BPV thru tree post rig; 1-2' ext. used, tagged ~ 102" ***Complete*** (Best/Wortham) Page 1 of 2 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 5/22/2008 _ _ __ Digital, Well File Page 2 of 2 ! i S-33 4/28/2008 ***WELL S/I ON ARRIVAL***(post rwo) ASSIST CH2MHILL W/ CRANE TO PULL BPV, PULLED B&R FROM RHC AT 8658' MD ' Pl7CCE6'B'ER"6L`R'AT'ST~5Z33~'S'~ PULLED BK-DGLV AT ST #4 (4810' MD), SET BK-LGLV AT ST #5 (3328' MD). RIH W/ 4 1/2" OK-6, BK-OGLV (ST #4, 4810' MD) ***JOB IN PROGRESS, CONTINUED ON 4/29/08 WSR*** S-33 4/28/2008 T/I/O=MV/0+/0. Temp=Sl. Remove cellar liner & half-drum (post-RWO). Cellar liner still frozen in place. Installed heater trunk in cellar to thaw. ** Note: Master valve is padlock closed. S-33 4/29/2008 T/I/0=0/0/0. Temp=Sl. Remove cellar liner & half-drum (post-RWO). Heater has been removed, cellar liner has frozen in place. Requested ICE deliver another. S-33 4/29/2008 T/I/0= 0/0/0. Temp= Hot. Remove cellar liner & half drum. Cellar liner and half drum has been removed. S-33 4/29/2008 ***CONTINUED FROM 4/28/08 WSR***(post rwo) SET BK-OGLV AT ST #4 (4810' MD), PULLED EMPTY RHC PLUG BODY AT 8,658' MD TAGGED HARD BTM C~3 9,193' SLM W/ 3.50" CENT, S-BLR (sample of parrifin) RAN SBHPS AS PER PROGRAM, GOOD DATA ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR'** S-33 5/4/2008 T/I/0= 280/820/0. Temp= Hot. IA FL (GLE). ALP= Open C~ casing valve. IA FL @ 3948' (1104' above sta# 4,104 bbls, 2.5 mmscfpd). S-33 5/14/2008 ****WELL S/I ON ARRIVAL*** SET SLIP STOP C-SUB C~3 3450' SLM PULL ST# 5 BK-LGLV (3328' MD) ***CONT ON 5-15-08 WSR*** S-33 5/15/2008 ***CONT FROM 5-14-08*** SET ST# 5 BK-LGLV (3328' MD) PULLED EMPTY SLIP STOP C-SUB (3450' SLM) ***WELL LEFT S/I, NOTIFY PAD OP*** Print Date: 5/22/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer.aspx 5/22/2008 • • BP EXPLORATION Operations Summary Report Page 1 of 11 (Legal Well Name: S-33 'Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date '~I From - To Hours 1 Task Code NPT 4/11 /2008 ~ 18:00 - 22:00 ~ 4.00 ~ MOB ~ P 22:00 - 23:00 I 1.00 I MOB I P 23:00 - 00:00 1.00 MOB P 4/12/2008 00:00 - 01:30 1.501 MOB P 01:30 - 16:00 14.50 MOB P 16:00 - 18:30 2.50 MOB P 18:30 - 19:30 19:30 - 21:30 21:30 - 00:00 4/13/2008 00:00 - 00:30 00:30 - 02:30 02:30 - 05:00 05:00 - 07:30 07:30 - 10:30 10:30 - 12:00 12:00 - 13:30 13:30 - 17:30 17:30 - 18:00 18:00 - 20:00 1.00 I MOB I P 2.00 MOB P 2.50 RIGU P 0.50 WHSUR P 2.00 WHSUR P 2.50 KILL P 2.501 KILL I P 3.00 WHSUR P 1.50 BOPSU P 1.50 BOPSU P 4.00 BOPSU P 0.501 BOPSURP 2.001 WHSUR I P Phase Description of Operations PRE Bridle up and R/D rig floor. Prepare to move off Well DS 15-32A. Attempt to make contact with AOGCC ~ 18:00 hrs. Left 24 hour notice on voice mail of upcoming BOPE test on S-33. PRE PJSM. Move off DS 15-32A and stage rig to lower derrick. Set rig down. PRE PJSM. Lay derrick down. Prepare to move BOPE out of cellar onto traveling skid. PRE Move BOPE out of cellar onto traveling skid. Install front booster wheels. PRE Move rig from DS-15 to S-Pad. Arrive at S-Pad ~ 16:00 hrs. PRE Spot rig on S-Pad. PJSM with rig crew. Discuss rigging up procedures and hazard related to removing the booster wheels and preparing location for rig. Remove rear booster wheels. Remove BOPE from carrier and secure in cellar. Spread herculite around well S-33 and place rig mats on same. At 18:00 hrs, contact AOGCC Chuck Scheve and gave update on upcoming ROPE Test for tomorrow morning. PRE PJSM with rig crew. Discuss procedures and hazard related to raising the derrick. Assign personnel job assignments and make sure each person understand his responsibilities. R/U loader to derrick break over line. Raise and secure derrick. R/U rig floor tuggers and cattle chute in "V" door. PRE Jack up rig and move onto S-33. Shim and set rig down. PRE Move equipment and R/U cellar. Set slop tank under conveyor. P/U and spot #2 pump and #4 generator modules. R/U rig floor. Accent rio at 24:00 hrs. DECOMP P/U and R/U DSM lubricator and equipment. Pressure test lubricator to 500 si, nod test. Pull BPV. R/D DSM tools and equipment. Bring 120 deg F seawater into pits. DECOMP Spot vac trucks for displacement. R/U circulating lines in cellar to wellhead. R/U to reverse circulate. Thaw out kill line. Continue rigging up rig floor. DECOMP PJSM with rig crew and CH2MHill. Go over pre-job check list for displacing and killing well. Discuss job assignments for rig personnel and CH2MHill vac trucks. Make sure each person understands to stop the job if anything looks like it is not right. Reverse circulate 91 bbls at 5 bpm with 1000 psi until diesel cleans out of tubing. R/U and circulate down the tubing taking returns to the slop tank at 5 bpm with 1160 psi. DECOMP Monitor, well dead. Blow down circulating lines. R/U, set, and test TWC to 3500- si from the to for 10-mins 1000- si fr m below for 30-mins each charted. Good, solid tests. DECOMP Nipple down tree. Terminate control lines. Screw in a 4-1/2" TDS XO for 9-1/2 turns into the hanger. DECOMP PJSM. N/U BOPE and 11" x 13-5/8" Adaptor Flange. DECOMP R/U for BOPE testing. Install Drilling Riser and air boots. DECOMP Pressure test BOPE to 250-psi low and 3500-psi high using 4" and 4-1/2" test joints. DECOMP Rig Down test equipment, bleed down lines. Check OA and no leaks from OA into the half drum provided in the cellar for containment. Blow down circulating lines. DECOMP R/U Doyon tubing tongs and handling equipment. M/U floor Printed: 5/15/2008 9:19:21 AM • • BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code ! NPT Phase Description of Operations 4/13/2008 18:00 - 20:00 2.00 WHSUR P DECOMP valve and landing joint to pull hanger. Test #2 mud pump. Install lubricator extension. 20:00 - 21:00 1.00 WHSUR P DECOMP P/U DSM lubricator, tools and equipment. R/,~I lilbriratnr and pressure test to 500-psi, good test. Pull TWC, no pressure under TWC. UD TWC. R/D DSM lubricator and equipment. 21:00 - 21:30 0.50 PULL P DECOMP P/U landing joint. RIH and M/U into hanger and top drive. BOLDS. Pull hanger to rig floor. Hanger broke free at 125,000-Ibs, tubing came free with 145,000-Ibs up weight. 21:30 - 22:30 1.00 PULL P DECOMP Circulate surface to surface at 10-BPM with 650-psi. No gas or losses during circulation. Monitor well. Blow Down circulating lines and R/U to POOH. 22:30 - 23:00 0.50 PULL P DECOMP Break out landing joint and hanger. UD same. Blow down circulating lines and top drive. 23:00 - 00:00 1.00 PULL P DECOMP POOH with 4-1/2" tubing 1x1 and UD through Pipe Shed. 4/14/2008 00:00 - 08:30 8.50 PULL P DECOMP POOH with 4-1/2" tubing 1x1 and UD in pipe shed. Pulled 90 joints at 03:42 hrs, 135 joints at 0510-hrs. 150-jts at 0615-hrs. 198-jts at 0730-hrs. Recovered 223-joints 4-1/2", 12.6-Ib, NSCT tubing, 9.03' Cut-off joint, 5-GLMs, 1-SSSV, 1 Parker SWS Nipple, 26 LaSalle Clamps, and 3 SS-bands. 08:30 - 09:30 1.00 PULL P DECOMP Remove 4-1/2" tubing handling equipment. Clear and clean rig floor. 09:30 - 11:00 1.50 FISH P DECOMP PJSM. Bring Baker BHA components to rig floor. M/U Dress-off BHA: 4-9/16" ID Shoe, Washpipe Extension, 2-ea Boot Baskets, 7-5/8" Casing Scraper and 6-4-3/4" Drill collars. Total length of BHA #1- 227.64' 11:00 - 18:30 7.50 FISH P DECOMP RIH Dress-off BHA on 268 joints of 4" HT-38 drill pipe from pipe shed 1 xi . Work casing scraper 4 times through 6300' to 18:30 - 19:00 0.50 FISH P DECOMP P/U joint #269 and establish parameters of Up Wt-170,000 Ibs; Down Wt- 160,000 Ibs; Rotating Wt- 165,000 Ibs at 30 rpm with 3000 ft-Ibs free torque; Pump Rate at 6 bpm with 870 psi. Continue RIH and taa tubina stub at 8716'. Rotate at 20 rpm with 3000 ft-Ibs free torque. Work over tubing stub, torque increased to 5000 ft-Ibs to get over the tubing stub and immediately cleaned up without taking weight. Continue swallowing 14' of the tubing stub to a final depth of 8730'. Worked over tubing stub 6 times. Slight rotation needed to work tubing stub into mill. Slight overpull pulling off tubing stub the first 2 times. Cleaned up without any overpull after those first 2 times. 19:00 - 20:00 1.00 FISH P DECOMP Pump high visc sweep at 10 bpm with 2435 psi. Sweep left work string at 8730' and brought back moderate amount of solids to surface consisting of metal scale and waxy paraffin type substance. 20:00 - 20:30 0.50 FISH P DECOMP Monitor well. Blow down circulating lines, install stripping rubber, and air slips to POOH. 20:30 - 23:00 2.50 FISH P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 23:00 - 00:00 1.00 FISH P DECOMP POOH with Dress-off BHA. UD BHA and stand back 2 stands of 4-3/4" drill collars. 4/15/2008 00:00 - 01:30 1.50 FISH P DECOMP Clean and clear rig floor. Prep rig floor for SWS. 01:30 - 03:00 1.50 EVAL P TIEB1 PJSM with SWS. Discuss R/U procedures and wireline safety. R/U SWS E-Line. Flag off danger zones. 03:00 - 09:30 6.50 EVAL P TIE61 Check at surface logging tool. RIH with USIT logging tool to Printed: 5/15/2008 9:19:21 AM LJ BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date I', From - To ', Hours Task Code NPT Phase Description of Operations 4/15/2008 103:00 - 09:30 6.501 EVAL P TIEB1 7000'. Repeat pass with the USIT loaned from 6900' to 6600 in 09:30 - 10:00 0.50 EVAL P TIEB1 10:00 - 13:00 3.00 EVAL P TIEB1 13:00 - 14:00 1.00 EVAL P TIEB1 14:00 - 00:00 10.00 EVAL P TIEB1 4/16/2008 100:00 - 01:00 I 1.001 EVAL I P I ITIEBI 01:00 - 02:30 1.50 EVAL P TIEB1 02:30 - 03:30 1.00 DHB P TIEB1 03:30 - 04:00 0.50 DHB P TIEB1 04:00 - 04:30 0.50 DHB P TIEB1 04:30 - 05:30 1.00 DHB P TIE61 05:30 - 06:00 0.50 DHB P TIEB1 06:00 - 09:00 3.00 DHB P TIEB1 09:00 - 10:00 1.00 DHB P TIE81 10:00 - 11:30 1.50 FISH P TIEB1 11:30 - 13:00 1.50 FISH P TIE61 13:00 - 14:00 1.00 FISH P TIEB1 14:00 - 14:30 0.50 FISH P TIEB1 14:30 - 17:30 3.00 FISH P TIEB1 cemenUcorrosion mode. RBIH to 7000' and log main pass up to surface in cemenUcorrosion mode. Both main and repeat passes were made at 3000'/hr. 6 deg, 5" resolution. R/D and remove USIT tool. Prepare SFRT tool, rehead wireline cable. R/U and calibrate the SFRT tool at surface. RIH with SFRT to 7000' and lop main pass up to 6600'. Made stops each 4' for 1 minutes and 20 second intervals. RBIH and log in high resolution mode from 6810' to 6650'. Made stops each 4' for 2 minutes and 40 second intervals. Continue running SFRT and log in high resolution mode from 6810' to 6650'. Made stops each 4' for 2 minutes and 40 second intervals. R/D SWS SFRT Logging Tool. R/D SWS E-Line equipment and tools. P/U HES 7-5/8" RBP. RIH with RBP on 4" HT-38 drill pipe from derrick to 2732'. Establish parameters of Up Wt- 78,000 Ibs; Down Wt- 82,000 lbs. Set HES 7-5/8" RBP with 1/2 left hand turn. Set 15,000 Ibs on RBP. Put 1/4 left hand turn, establish RBP set with 5000 Ibs overpull. Put 1/4 left hand turn and pull off RBP. Set top of fishneck at 2732' and 2736' middle of element. POOH and UD 1 joint of drill pipe. R/U casing testing equipment. Pressure test RBP and CSG to 1500 psi. Hold test for 15 charted minutes, good test. PJSM rig crew and CH2MHill vac truck. Discuss Doyon and CH2MHill displacement procedures. Assign assignment to rig personnel. Reassure all lines are correct and secure. Pump 20 bbl high visc spacer and 113 bbls of 9.8 ppg brine. POOH 1 stand and R/U sand hopper on drill pipe. Dump 1400 Ibs of 20-40 River Sand on Top of RBP. Pump Down Drill String at 1 bpm to clear Drill Pipe. Run back in hole and tag top of sand at 2684'. POOH with Drill Pipe and RBP Setting Tool. UD Setting Tool. M/U Baker Inside Cutter BHA. Total Length of Cutter above Knives = 7.91'. RIH with 27 Stands of DP to 2572'. Take Initial Parameters of Up Wt- 82,000 Ibs; Down Wt- 75,000 Ibs; Rotating Wt- 80,000 at 70 RPM with 3000 ft-Ibs free torque; Pump Rate at 2-6 bpm with 160-700 psi. Locate Casing Collars. Make passes with pump pressure at 150 psi, 170psi, and 190 psi. Tough to find Collars on NSCC. Locate Collars at 2601' and 2640'. PJSM with Rlg Crew, Vac Truck Drivers, and Little Red. Spot Vac Trucks for Cellar and on Slop Tank. Spot Up Little Red. Cut casing cut at 2625' at 70 rpm 4000-5000 ft-Ibs torque. Cut took - 10 minutes. Pump 50 bbs 120 deg diesel at 910 psi and chase with 30 bbls 9.8 ppg brine to spot diesel on back of 7-5/8" casing. Shut down pumps and allow diesel to soak for 30 minutes. Chase diesel up the hole with 120 bbls of 9.8 ppg brine at 5 bpm with 810 psi. Shut in and allow diesel to soak for 10 more minutes. Continue pumping at 5 bpm with 810 psi to clean wellbore and Printed: 5/15/2008 9:19:21 AM C] BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code ~ NPT I! Phase Description of Operations 4/16/2008 14:30 - 17:30 3.00 FISH P TIE61 displace the well to 9.8 ppg brine. Continue pumping one more bottoms up at 5 bpm with 450 psi. Confirm 9.8 ppg brine in and out. 17:30 - 18:30 1.00 FISH P TIEB1 Monitor well. POOH standing back with 4" HT-38 drill pipe in derrick. 18:30 - 19:00 0.50 FISH P TIEB1 POOH and UD casing cutter and BHA #3. 19:00 - 19:30 0.50 FISH P TIEB1 P/U landing joint and M/U pulling tool. RIH and pull wear ring. 19:30 - 20:00 0.50 FISH P TIEB1 P/U and M/U ITCO spear assembly consisting of ITCO spear and 6.767" grapple and bull nose stub, packoff, x/o, and stop sub. Total length of BHA #3- 12.21' 20:00 - 21:00 1.00 FISH P TIEB1 PJSM with rig crew and Baker fisherman. Discuss fishing and pulling procedures for 7-5/8" CSG. BOLDS. P/U Doyon casing handling equipment and RU on rig floor. 21:00 - 21:30 0.50 FISH P TIEB1 RIH and en a e 7-5/8" casin han er with s ear and ra le. Pull on 7-5/8" casin .Casing came free at 140,000 Ibs up weight. String up weight at 113,000 Ibs. Pull casing hanger to rig floor. Break out and UD spear assembly and casing hanger. 21:30 - 00:00 2.50 FISH P TIEB1 POOH with 7-5/8" casing and UD in pipe shed 1x1. Average break out torque at 28,000 ft-Ibs. 4/17/2008 00:00 - 01:30 1.50 FISH P TIEB1 Continue to POOH with 7-5/8" casing and UD in pipe shed 1x1. Average brake out torque at 28,000 ft-Ibs. Recovered 66 full joints and 1 cut joint at 34.39'. Casing in good condition with no noticeable corrosion. 01:30 - 02:30 1.00 FISH P TIE61 P/U Baker spear assembly and break out components. 02:30 - 03:30 1.00 FISH P TIEB1 Check 7-5/8' casing tally. Attempt to figure out length of cut joint downhole. Decide to RIH w/ casing cutter and re-cut casing below collar. Send for Baker casing cutter. 03:30 - 04:30 1.00 FISH P TIEB1 P/U Baker Multi String Casing Cutter BHA consisting of casing cutter, stabilizer, x/o subs. Total length of BHA#4- 7.91' 04:30 - 05:00 0.50 FISH P TIE61 RIH with BHA #4 on 4" HT-38 drill pipe from derrick to 2637' (12' dee er than last cut . 05:00 - 05:30 0.50 FISH P TIEB1 Establish parameters of Up Wt- 75,000 Ibs; Down Wt- 80,000 Ibs; Rotating Wt- 80,000 Ibs at 50 rpm with 2500 ft-Ibs free torque; Pump Pressure- 600 psi at 5.75 bpm. Cut casing at 2637'. Pump pressure decreased to 300 psi at 5.75 bpm indicating casing cut. 05:30 - 06:00 0.50 FISH P TIE61 CBU to help clean out 10-3/4" casing at 5.5 bpm with 250 psi. Blow down top drive. 06:00 - 07:00 1.00 FISH P TIE61 POOH standing back 4" HT-38 drill pipe in derrick. 07:00 - 07:30 0.50 FISH P TIE61 UD Multi String Cutter BHA. 07:30 - 08:30 1.00 FISH P TIEB1 M/U 7-5/8" Ca in Sear BHA. 08:30 - 09:30 1.00 FISH P TIE61 RIH with Spear to 2600' on 4" HT-38 drill pipe from derrick. 09:30 - 10:00 0.50 FISH P TIEB1 Take Intital Parameters P/U Wt = 80,000 Ibs S/O Wt = 82,000 Lbs Circ at 5 bpm at 300 psi. Engage Fish at 2625', swallow with 7' of spear. Required 45,000 Ibs over pull to break fish loose. P/U and Confirm free. Repeat twice to ensure fish latched and stacking out at same depth. 10:00 - 11:30 1.50 FISH P TIEB1 Monitor Hole for 15 mins. Blow Down Top Drive and POOH with Spear and Fish. 11:30 - 12:30 1.00 FISH P TIE61 B/O and UD Spear for 7-5/8" and BHA, UD Fish. Reco~ vered 12.87' of 7-5/8" casin To of Fish t 12:30 - 13:00 0.50 FISH P TIEB1 Check Wear Ring Placement with FMC and on set Depth of Printed: 5/15/2008 9:19:21 AM • • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT I Phase ~, Description of Operations 4/17/2008 12:30 - 13:00 0.50 FISH P TIE61 False Bowl. Fully Seated. 13:00 - 14:30 1.50 FISH P TIE61 M/U Dress Off BHA with 9-5 7- WP Extension. 7-5/8" Dress Off Mill, Drive Bushing, XO Sub, XO Sub, 10-3/4" Casing Scraper, XO Sub, Boot Baskets, XO Sub, Bit SUb, Oil Jar, XO SUb, and 6 DC's. Total Length = 233.01 ft. While Attempting to Make Up Collars and RIH Rotary Tagged Up on False Bowl. Bowl ID too small. New Bowl Measured 9.48" ID. PIU and Stand Back BHA. 14:30 - 15:30 1.00 FISH P TIEB1 Consult with FMC, Baker Fishing and Town. Need to pull False Bowl to make Dress Off Run -Discuss Best Way to pull False Bowl due to real tools not available to fish False Bowl. 15:30 - 16:00 0.50 FISH P TIE61 PJSM with rig Crew on Splitting Wellhead between Casing and Tubing Spool. Gather Tools and R/U to Pull Flow Riser. Drain BOP Stack. 16:00 - 17:00 1.00 WHSUR P TIEB1 N/D BOP's and Tbg Spool from Casing Spool. Set Back BOP's and Tbg Spool. Pull False Bowl from Casing Spool. 17:00 - 18:30 1.50 WHSUR P TIEB1 Clean Face of Casing Spool and API Ring Groove. Install New API Ring. Set Tbg Spool and BOPS back on Casing Spool. Torque Up Nuts with Sweeny Wrench. 18:30 - 19:00 0.50 WHSUR P TIEB1 R/U BOPE testing equipment and set test plug. 19:00 - 20:00 1.00 BOPSU P TIEB1 Attempt to pressure test wellhead break to 250 psi low pressure and 3500 psi iq pressure. 20:00 - 22:30 2.50 BOPSU N SFAL TIEB1 Change out test plug packoff rubbers 3 times. Change out test plug. Pressure test wellhead break to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 chrarted minutes. Test was witnessed by Doyon Toolpusher and BPX WSL. 22:30 - 00:00 1.50 FISH P TIEB1 P/U Dress Off BHA from derrick and RIH on 4" HT-38 drill pipe from derrick. 4/18/2008 00:00 - 01:00 1.00 FISH P TIEB1 RIH with 26 stands of 4" HT-38 drill pipe from derrick to 2605'. 01:00 - 02:00 1.00 FISH P TIEB1 Slip and cut 80' of drill line. Check and maintain brake linkage. 02:00 - 04:00 2.00 FISH P TIEB1 M/U to top drive. Establish parameters of 75,000 Ibs Up Wt; 75,000 Ibs Down Wt; 75,000 Ibs Rotating Wt at 60 RPM with 2000 ft-Ib free torque. RIH and dr rLtaq casing stub at 2637'. Pump at 8.25 bpm with 570 psi. Milled over and swallow over casing stump to 2643'. No increase from initial parameters while milling over casing stump. Set 5000 Ibs WOB and allow to drill off. Dressed off casing stub to 2638'. Pump high visc sweep. Pump Safe Surf O sweep. Reamed rotary shoe over casing stub 5 times without any problems. 04:00 - 04:30 0.50 FISH P TIEB1 Launch high visc sweep at 10 bpm with 750 psi. Safe Surf O and high visc sweep brought back extra oily paraffin material to surface. 04:30 - 06:00 1.50 FISH P TIEB1 Pump dry job. Blow down top drive and circulating lines. POOH standing back 4" HT-38 drill pipe in derrick. 06:00 - 06:30 0.50 FISH P TIEB1 POOH and L/D dressoff assembly. Stand back 2 stands of 4-3/4" drill collars. 06:30 - 08:30 2.00 CASE P TIEB1 Pull wear ring and R/U rig floor to run 7-5/8" casing with Doyon casing equipment. 08:30 - 16:00 7.50 CASE P TIEB1 PJSM. P/U 7-5/8" casing assembly consisting of Bowen Casing Patch, x/o pup, Baker external casing packer, and HES ES cementer. RIH on 7-5/8", 29.7#, L-80, TC-1I casing as per tally. Baker locked all connections below ES cementer. Ran 1 Printed: 5/15/2008 9:19:21 AM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 4/18/2008 08:30 - 16:00 7.50 CASE P TIEB1 free floating centralizer on each joint of casing above ES cementer. All connections made up to 9900 ft-Ibs using Doyon Torque Turn Equipment. Jet Lube Seal Guard pipe dope was used on connections. RIH to 2635'. 16:00 - 16:30 0.50 CASE P TIE61 Establish parameter of Up Wt- 113,000 Ibs; Down Wt- 113,000 lbs. Engage casing stub. P/U 15,000 Ibs to set grapple. S/O 40,000 Ibs to ensure casing patch fully swallowed. Casing patch swallowed 2.5'. P/U to 300,000 Ibs to ensure set. 16:30 - 17:30 1.00 CASE P TIEB1 Change out bails and R/U cement head. Pull 100,000 Ibs overpull on casing stub and hold. 17:30 - 18:30 1.00 CASE P TIEBi Pressure test casing to 1000 psi and hold for 15 charted minutes, good test. Increase pressure on casing to 1600 psi to inflate acker. Packer bleed off and trapped 1300 psi. Monitor pressure. Increase pressure to 2000 psi to pressure test casin .Hold pressure for 30 charted minutes, ood test. Bleed pressure off casing. 18:30 - 19:00 0.50 CASE P TIEB1 Hold PJSM with rig crew and CH2MHill vac truck crew. Discuss procedure for pressuring up the 10-3/4" x 7-5/8" annulus to 500 psi. Monitor all lines, make sure vac truck is in cellar and prepared to catch anything coming from the conductor pipe. 19:00 - 19:30 0.50 CEMT P TIEB1 Pressure u and o en ES Cementer with 3300 si. Establish circulation. Shut down pumping, close OA valves and annular preventer, open hot tap valve on conductor pipe. Pressure test OA to 500 psi. Hold pressure for 10 minutes while monitoring hot tap on conductor pipe. Pressure held with no leak in cellar. Report results to town. 19:30 - 20:00 0.50 CEMT P TIEB1 Hold PJSM with rig crew, CH2MHill vac truck drivers, Schlumberger cementers. Discuss safety policies, proper foot wear while working outside, high pressure hoses and hard lines with secondary containment, and assign work assignments. Discuss cementing procedures and contingencies. 20:00 - 20:30 0.50 CEMT P TIEB1 Circulate warm brine to warm wellbore at 4.4 bpm with 200 psi while making final R/U. Check lines through choke and to slop tank. Make sure everything is secure and lined up properly. Place D110 retarder where needed. 20:30 - 21:30 1.00 CEMT P TIEBi Pressure test cementing lines to 4500 psi. Bleed pressure and start cement job. Pump 132 bbls 15.8 ppg Class G cement with .2%gps D047 antifoam, .05% gps D185 low temperature dispersant, 2% gps D600G gas block, .17% gps D186 accelerator. First 10-15 bbls of cement had red dye marker. Pump cement at 5.5 bpm with 750 psi. Turn over to rig pump. Drop closing dart and displace cement with 9.8 ppg brine at 6 bpm with 330 psi. Caught cement after pumping 42 bbls. Continue displacing cement at 6 bpm with 440 psi taking return to the pits. After displacing 50 bbls, closed annular preventer and o en OA to slo tank and continued dis lacement at 5 b m with 460 si. Watch for cement at surface. Cement to surface after dis lacin 85 bbls while pumping at 4.5 bpm with 1110 psi. Maintain 500 psi backpressure with choke while pumping at 2.3 bpm with 1300 psi pump pressure. Maintain 500 psi for the rest of the cement job. Bump plug with 117.24 bbls displacement at 0.9 bpm with 1390 psi. CIP at 21:30 hrs. Printed: 5/15/2008 9:19:21 AM BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/18/2008 20:30 - 21:30 1.00 CEMT P TIEB1 Increase pressure and close ES Cementer with 2250 psi. 21:30 - 22:00 ~ 0.501 CEMT ~ P ~ ~TIEB1 22:00 - 22:30 0.50 WHSUR P TIEB1 22:30 - 00:00 1.50 WHSUR P TIEB1 4/19/2008 100:00 - 01:30 1.501 WHSUR P TIEBI 01:30 - 02:30 1.00 WHSUR P TIE61 02:30 - 04:30 2.00 WHSUR P TIEB1 04:30 - 05:30 1.00 WHSUR P TIEB1 05:30 - 06:00 0.50 WHSUR N SFAL TIEB1 06:00 - 09:00 09:00 - 09:30 09:30 - 10:30 3.001 WHSUR I N I SFAL I TIE61 0.50 WHSUR P 1.00 DRILL P 10:30 - 11:00 I 0.501 DRILL I P 11:00 - 13:30 I 2.501 DRILL I P 13:30 - 14:00 0.50 DRILL P 14:00 - 14:30 0.50 DRILL P TIEB1 TIEB1 TIEB1 TIE61 TIEB1 TIEB1 Definite indication at rig floor of cementer closing. Hold 2170 psi. Release pressure, with no flow back. Flush BOPE and circulating lines to clear cement. R/D cement head and x/o pup. N/D BOPE and lift out of way. Install false bowl as per FMC Tech. M/U emergency slips and set in false bowl. Slack off and set emergency slips with 100,000 lbs. R/U Wachs cutter and cut casing stub at casing spool. R/D Wachs cutter. Clean casing cut. ,N.(~ Install 7-5/8" packoff. 1~1~ ~n~ ~ C~ Set BOPE on wellhead. fyJB"'80PE. Attempt to test packoff and wellhead break. Pressure would hold at 2000 psi, but could not get a test at 3800 psi. Investigate the problem. Continue trouble shooting wellhead and packoff. Increase LDS torque from 450 ft-Ibs to 500 ft-Ibs. Pressure test held 3000 psi, but no more. Increase LDS torque to 600 ft-Ibs. Pressure test 7-5/8" packoff and tubino spool/casina spool break to 3750 psi for 30 minutes. P/U test joint and wear ring. Set wear ring. L/D test joint. P/U and RIH with clean out assembly (BHA # 7) consisting of 6-3/4" rock bit, (2) 5" boot baskets, casing scraper, bit sub, bumper sub, jars, x/o sub, and 2 stands of 4-3/4" drill collars from derrick. Total length of BHA #7- 219.56' RIH with clean out assembly on 4" HT-38 drill pipe to top of cement at 2579'. Establish parameter of Up Wt- 80,000; Down Wt- 80,000 Ibs; Rotating Wt- 80,000 Ibs at 50 rpm with 2000 ft-Ibs free torque; Pump Rate- 6 bpm with 420 psi. Tag closing plug at 2580'. Drill through closing plug, cementer, and cement to 2686' with 7000 to 9000 Ibs WOB. Increased to 60 rpm and 2500 to 3000 ft-Ibs torque. Continue to drill through cement to the top of sand at 2684'.. Pump 20 bbl high visc sweep at 10 bpm with 1550 psi. test. Bleed off pressure, blow down lines. 14:30 - 15:30 1.00 DRILL P TIEB1 +POOH standing back 4" HT-38 drill pipe in derrick. 15:30 - 16:00 0.50 DRILL P TIEB1 POOH and L/D clean out assembly. Stand back 2 stands of 4-3/4" drill collars in derrick. 16:00 - 17:00 1.00 DHB P TIEB1 P/U RCJB (BHA #8) consisting of RCJB mill, x/o sub, 2 boot baskets, bit sub, bumper sub, pumpout sub, x/o sub, and 2 stands of 4-3/4" drill collars from derrick. Total length of BHA #8- 217.07' 17:00 - 17:30 0.50 DHB P TIEB1 RIH with 27 stands of 4" HT-38 drillpipe picked up from derrick. 17:30 - 18:00 0.50 DHB P TIE61 Establish parameters of Up Wt- 80,000 Ibs; Down Wt- 80,000 Ibs; Rotating Wt- 80,000 Ibs at 40 rpm with 2000 ft-Ibs free torque; Pump Rate a 9.5 bpm with 2600 psi. Wash through . sand from 2686' to 2722. Hit a hard spot in sand at 2702'. Worked through hard spot after picking up and hit it a second time. Continue washing to 2722'. Printed: 5/15/2008 9:19:21 AM • BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Spud Date: 10/6/1992 Event Name: WORKOVER Start: 4/12/2008 End: 4/22/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/22/2008 Rig Name: DOYON 16 Rig Number: Date ;From - To I Hours '~ Task .Code NPT Phase Description of Operations 4/19/2008 18:00 - 19:00 1.00 DHB P TIEB1 Pump high visc sweep. Sweep brought only sand out of hole. Blow down top drive. 19:00 - 20:00 1.00 DHB P TIEB1 POOH standing back 4" HT-38 drill pipe in derrick. 20:00 - 20:30 0.50 DHB P TIE61 POOH with RCJB BHA #8. Stand back 2 stands of 4-3/4" drill collars. Brake out RCJB, recovered 2 fist size chunks of closing plug, no metal. 20:30 - 21:00 0.50 DHB P TIEB1 Re-run RCJB BHA #8 on 2 stands of 4-3/4" drill collars. 21:00 - 21:30 0.50 DHB P TIEB1 RIH with RCJB on 27 stands of 4" HT-38 drill pipe from derrick. 21:30 - 22:00 0.50 DHB P TIE61 Establish parameters of Up Wt- 80,000 Ibs; Down Wt- 80,000 Ibs; Rotating Wt- 80,000 Ibs at 40 rpm with 2000 ft-Ibs free torque; Pump Rate a 9.5 bpm with 2600 psi. Wash through sand from 2722' to 2727. 22:00 - 22:30 0.50 DHB P TIE61 CBU at 9.5 bpm with 2700 psi until sand cleaned up at shakers. 22:30 - 23:00 0.50 DHB P TIEB1 POOH with RCJB standing back 4" HT-38 drill pipe in derrick. 23:00 - 00:00 1.00 DHB P TIE61 POOH with BHA #8 standing back 2 stand of 4-3/4" drill collars. L/D RCJB. No recovery. UD RCJB 4/20/2008 00:00 - 00:30 0.50 DHB P TIEB1 P/U HES retrieving tool and RIH on 4" HT-38 drillpipe from derrick to 2670'. 00:30 - 01:00 0.50 DHB P TIEB1 Establish parameters of Up Wt-80,000 Ibs; Down Wt-80,000; Pump Rate at 6 bpm with 400 psi. Wash down through top of sand at 2727' to top of HES RBP at 2732'. Engage RBP. Ensure engagement by P/U 10,000 overpull and slacking off to neutral. 01:00 - 02:00 1.00 DHB P TIEB1 Hold PJSM with rig crew and CH2MHill vac truck drivers. Discuss displacement procedures and safety. Pump high visc spacer and displace well to seawater at 10 bpm with 600 psi. 02:00 - 02:30 0.50 DHB P TIE61 Release HES RBP and monitor well. Blow down top drive. 02:30 - 07:30 5.00 DHB P TIEB1 POOH standing back 4" HT-38 drill pipe in derrick. First stand off bottom pulled with no problems. Noticed trouble pulling RBP through ES cementer. RBP hung up on each casing collar. RBP stuck at 2487'. Unable to pull up or go down. M/U top drive and circulate at 8 bpm with 390 psi, rotate right at 10 rpm and 2000 to 3000 ft-Ibs torque. Increase pull to 30,000 Ibs overpull where RBP came free. Continue POOH. RBP continue hanging up each casing collar. Some collars were able to pull through with straight pull about 1/2 needed to be rotated and pumped out. Hung up badly at 2487', 2340', 2259', and 1990'. Last 1000' pulled some what free of problems. 07:30 - 08:30 1.00 DHB P TIE61 RBP at Surface. Found 6" OD Aluminum cylinder around fish neck on RBP. Attempt to B/O from Retrieval Tool. Unable to get Overshot on retrieval tool to release. Found inner mandrel of RBP sheared and twit B/O RBP and Retrieval Tool Together and UD in Pipe Shed. B/O XO Pup Jt and L/D. 08:30 - 09:30 1.00 BOPSU P DECOMP Clean and Clear Rig Floor. Pull Wear Ring and R/U to Test BOP's 09:30 - 16:00 6.50 BOPSU P DECOMP Pressure Test BOP's. 250 psi low and 3500 psi high, hold each test for a minimum of 5 mins. Witness to Test Waived by Bob Noble of AOGCC. Witnessed by BP WSL and Doyon Tool Pusher. Fought problems with Test Plug Leaking by. Consulted with FMC and new Test Plug sent to Location. New test plug holding with out problems. Printed: 5/15/2008 9:19:21 AM BP EXPLORATION Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I, From - To Hours Task Code NPT -__ --__1 _-II 4/20/2008 109:30 - 16:00 6.501 BOPSURP 16:00 - 17:00 1.00 BOPSU P 17:00 - 18:00 1.00 DHB P 18:00 - 20:00 2.00 DHB P 20:00 - 20:30 0.50 DHB P 20:30 - 22:00 1.50 DHB P 22:00 - 23:30 1.50 DHB P 23:30 - 00:00 4/21 /2008 00:00 - 01:00 01:00 - 01:30 01:30 - 02:00 02:00 - 09:00 09:00 - 10:00 10:00 - i 1:30 11:30 - 16:30 0.50 DHB P 1.00 DHB P 0.50 DHB P 0.50 DHB P 7.00 PULL P 1.00 PULL P Page 9 of 11 Spud Date: 10/6/1992 Start: 4/12/2008 End: 4/22/2008 Rig Release: 4/22/2008 Rig Number: Phase Description of Operations DECOMP 1-Ann, Kill HCR, Valves 1,12,13,14 2-Manual Kill, Lower IBOP, Valves 9&11 3-Valves 5,8,10 & TIW 4- Valves 4,6,7, Dart Valve 5-Valve #2 6-Choke HCR 7-Choke Manual 8-4" Test Joint in Lower Pipe Rams 9-Blind Rams & #3 10-4-1/2" Test Joint and Lower Pipe Rams 11-Ann w/ 4-1/2" Test Joint 12-Koomey DECOMP R/D BOP Test Equipment and Set Wear Ring. DECOMP P/U 'unk millin assembl BHA # a consisting of 3.7" convex junk mill, bit sub, 4 joints of 2-7/8" PAC drill pipe, x/o sub, bumper sub, jars, pump out sub, x/o sub, and 2 stands of 4-3/4" drill collars from derrick. Total length of BHA #10- 336.26' DECOMP RIH with 50 stand of 4" HT-38 drill pipe from derrick to 5083'. DECOMP R/U equipment to test casing. Pressure test casing to 3500 psi for 30 charted minutes, good test. R/U test equipment DECOMP Continue RIH with 4" HT-38 drill pipe from derrick to 8694'. DECOMP Establish parameters of Up Wt-175,000 Ibs; Down Wt- 156,000 Ibs; Rotating Wt- 166,000 Ibs with 50 rpm and 3000 ft-Ibs free torque; Pump Pressure- 770 psi at 4 bpm. Continue RIH, touched top of tubing stub at 8716'. Tag up on FasDrill plug at 8804'. Drill FasDrill plug with original parameter. Increase pump rate to 7 bpm with 2200 psi. Maintain 2000 to 4000 Ibs WOB. Drill through FasDrill plug at 22:45 hrs. Well started loosin fluid at 280 b h. Push FasDrill plug through tubing tail pipe assembly to 8835'. P/U and run through tubing stub 2 more times to ensure clean. POOH to 8715' and monitor loss rate. DECOMP Circulate bottoms up at 7.5 bpm 2330 psi. Bottoms up brought a fair amount of gas to surface and cleaned up shortly. ~D namic loss rate decreased to 130 b h. DECOMP Continue circulating bottoms up a second and third time a 7.5 bpm with 2330 psi. During the second bottoms up another gas bubble broke out at surface. Third bottoms up was clean with no gas throughout the circulation. Dynamic loss rate at 130 bph. DECOMP Shut down pump and monitor well. Monitor well. Static loss rate 130 bph. Will maintain constant hole fill while POOH. DECOMP Blow down circulating lines and top drive. Monitor well. DECOMP POOH and L/D 4" HT-38 drill pipe in pipe shed 1x1. DECOMP L/D 4-3/4" DC's, 2-718 PAC DP, and Mill. FLuid Loss at -90 1.50 BUNCO RUNCMP Pull Wear Ring, R/U Torque Turn and Double Stack Power Tongs. M/U Compensator and Single Joint Elevators to Top Drive. Change Out Bails and Elevators. Gather Up other Equipment for Running Completion and organize jewelry in pipe shed. 5.00 BUNCO RUNCMP PJSM with Rig Crews on Running Completion. P/U and RIH Printed: 5/15/2008 9:19:21 AM BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: S-33 Common Well Name: S-33 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Spud Date: 10/6/1992 Start: 4/12/2008 End: 4/22/2008 Rig Release: 4/22/2008 Rig Number: Date ,From - To Hours Task Code NPT 4/21/2008 11:30 - 16:30 5.00 BUNCO 1P 16:30 - 00:00 I 7.501 RUN 4/22/2008 100:00 - 03:00 I 3.001 RU 03:00 - 03:30 I 0.501 RU 03:30 - 04:30 1.001 RNTBHa P 04:30 - 05:30 I 1.001 RNTBHG P 05:30 - 07:30 2.00 RNTBH(~ P 07:30 - 09:30 2.00 RNTBHa P 09:30 - 10:30 I 1.001 WHSUR I P Phase Description of Operations RUNCMP 4-1/2", 12.6# 13Cr Vam To Tb Com letion. 4-1/2" x 7-5/8" Unique Overshot, X-Nipple, Baker S-3 Packer, X Nipple, 5 GLM's and X-Nipple. Total of 210 Joints Run. M/U Vam Top Connection to 4440 ft-Ibs optimal torque. RUNCMP On Jt #76 (-3250') Tbg Took Wt. Sat Down on something. P/U and S/O again. Able to work through with 5,000 Ibs. Next joint#77 -set down in approxiamately same spot in joint. P/U and see approxiametly -10k over pull but fell off quickly. S/O again. Seeing Wt at Same Spot, P/U w/ no over pull. Make 1/4 turn and S/O. Able to go in hole. Joint #78 on saw very little if anything while S/O. Joint #79 setting down again, P/U and see -10K again but fell off quickly. S/O with 1/4 turn and able to continue in hole. Continue to see wt at -40' to42' interval on most joints while RIH, not catching on anything in Stack down hole somewhere. Able to get past each spot by lightly tagging and then turn pipe an inch or so to the right. Consult Anchorage on what is taking place. Continue to RIH. Most every joint caught something downhole. Most took a small amount of rotation to roll off. RUNCMP Continue P/U and RIH with 4-1/2", 12.6#, 13Cr, Vam Top Completion. Ran a total of 212 joints in hole. Continued touching something each joint ran in hole, did not need rotation to go past. Tagged top of tubing stub at 8720;. S/O and tag bottom set of shear pins at 8725' and shear at 5000 Ibs. Tag top set of shear pins at 8733' and shear with 7000 Ibs. No Go out at 8735'. Set 15,000 Ibs on No Go. Confirmed location and P/U to neutral point. P/U 2' and figured out spaceout. Static loss rate at 60 b h. RUNCMP POOH and UD joints 212, 211, and 210. P/U and RIH with 3 pups at 3.73', 9.73', and 9.80'. P/U joint 210 and RIH. TUBHGR P/U landing joint and M/U 11" FMC tubing hanger with CIW type H profile. Blank off control line ports, inspect hanger, and RIH. Land completion. RILDS. Final depth of Unique Overshot ~ 8732'. Up Wt- 143,000 Ibs and Down Wt- 130,000 lbs. TUBHGR R/U to displace well to seawater and corrosion inhibited seawater. Test circulating lines. TUBHGR Pump and spot PKR fluid at 6 bpm with 600 psi. TUBHGR Drop ball and rod and set packer and pressure test tubing to 3,500 si for 30 minutes on Chart, bled tubin down to 1 500 si, ressure u on IA to 3,500 si and hold fora 30 minute test on chart. Bled off tubing pressure to 0 psi sheared DCK valve, Circulated in both directions at 1,300 psi at 3 bpm WHDTRE R/D circulating lines, UD landing joint. Install TWC and test to 10:30 - 11:00 0.50 BOPSU P WHDTRE R/D B/D circulating lines, Vacuum out BOP Stack. 11:00 - 13:00 2.00 BOPSU P WHDTRE N/D BOPE, remove 13 3/8" x 11 5/8"spacer spool. 13:00 - 14:30 1.50 WHSUR P WHDTRE Prepare well head ,install adapter flange and test same to 5,000 psi for 30 minutes. 14:30 - 17:00 2.50 WHSUR P WHDTRE N/U Production Tree and test to 5,000 psi for 30 charted minutes. 17:00 - 18:00 1.00 WHSUR P WHDTRE P/U DSM Lubricator make up same an_d test to 500 psi. Pull TWC and UD DSM lubricator. Printed: 5/15/2008 9:19:21 AM Printed: 5/15/2008 9:19:21 AM 05/20/08 ~i~l'~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WP_II .Inh 3F itj~Ya+l ~~~ ~ V 1'd ~t LU~~ 1 n.. NO.4712 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPB-04A 12021150 -- -~~~ ~ MEM PROD PROFILE ~y 04/17/08 1 VVIVI VV 1 MPG-13 12021151 MEM INJECTION PROFILE sG .. 04/18/08 1 1 Z-26A 11978454 MEM GLS aUfp-p 04/23/08 1 1 Z-29 11978453 MEM GLS _ ~- 04/22/08 1 1 Y-36 12005204 MEM GLS ~/ _ 02/12/08 1 1 4-14A/S-37 12031471 PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-016 11966257 LDL - f (p 05/10/08 1 1 X-16A 11975771 _ USIT ~ - C 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 05-23A 118966257 USIT ( 05/13/08 1 1 S-33 11962596 USIT - 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT `~ - / 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT 'fib _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT p~.-U ( ! 02/18/08 2 1 05-226 11628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL 5 01/31/08 1 1 Z-10 12066520 RST ~ 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 DI CAL+c AI+V-~A~II~~ ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~ > 900 E. Benson Blvd. _ Anchorage, Alaska 99508 ~~ Date Delivered: ~ ~. ~~rini~ ~. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • ~\ 05/01 /08 ~chlum~err~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh # NO. 4686 Company: State of Alaska Alaska Oil & Gas Cons Comm A~ nv Attn: Christine Mahnken e~~~t+'~E16tl~~ MH! ~ ~ 2OQ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I nn nwsrrintinn rlnfc RI r`nlnr rn L5-24 11975769 PRODUCTION PROFILE W/FSI ':- 04/29/08 1 1 W-22 12066521 PRODUCTION PROFILE W/FSI e 04/14/08 1 1 05-34 11962597 DDL ( 04/16/08 1 1 S-33 11962596 SFRT 04/15/08 1 1 8-06 11999002 SCMT ( 04/19/08 1 1 04-42 11966253 LDL 04/15/08 1 1 D-10 11975766 PRODUCTION PROFILE ~ .. ~ (~ 04/24/08 1 1 rl-cAJC Al~nrvIJ VVLCVUt FStlalr 1 Cr .~ICarvlrvta HIVU Fitt UFiNIIVta UNt GUYY tAlitl 1 U: BP Exploration (Alaska) Inc. Petrotechnrcat Data Center I_R2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 { i, ~, `I ~'~~~Ir ~ ; 3 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 0 Anchorage, AK 99503-283 ATTN: Beth /~ Received by: • • /.'~-. • • :°~ ~ -;,~ 1,.1 , i ~ ~il ~ 13:x.: {p(Jr~P 59}y {"° ~ °"~"~1 ~' x ,~ ~., ~ ~~! ~ ~\~ ~ SARAH PALIN, GOVERNOR ~t ~S~ OII/ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSI:RQA7`IO1~T COMIrIISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. ; APR ~ ~~~~ PO Box 196612 Anchorage, AK 99519-6612 l~~ Re: Prudhoe Bay, Prudhoe Bay Oil Pool, PBU 5-33 - ~ ..... . N Sundry Number: 308-082 ~~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager. As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. 7 ~ Chair DATED this < day of April, 2008 Encl. ~,ttr~~~ STATE OF ALASKA ~~~ RE~/ ~/ 1j ~ ALA OIL AND GAS CONSERVATION COM~ION ~y APPLICATION FOR SUNDRY 20 AAC 25.280 1. Type of Request: ^ gbandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate Time Extensipmchorage ~ Alter Casin g ~ ~~ ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 192-102 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22293-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU S-33 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028257 69' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9510 9221 9430 9148 None 9199 Casin Len th Size MD TVD Burst Colla se' Structural C n uctor 76' 20" 76' 76' 1490 470 Surface 2922' 10-314" 2958' 2957' 5210 2480 Intermediate 8981' 7-5/8" 8981' 8740' 8180 5120 Prod c ion Liner 693' S-1/2" 8815' - 9508' 8589' - 9219' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9044' - 9252' 8797' - 8987' 4-1/2", 12.6# 13Cr80 8824' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker'SABL-3' packer Packers and SSSV MD (ft): 8763' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 5, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date 3-+3-~o~Q Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~, BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~~St Q~~ ~T Subsequent Form Required: y~~ APPROVED BY Y ~ ~ CCCJJJ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Re`Gis~d 06/2006 APPROVAL ~`~ MAR 08~~ Submit In Duplicate • • by c~~ S-33 Rig Workover Scope of Work: Expense RWO. Pull 4-'/z" completion, cut and pull 7 5/a" casing, run and cement to surface new 7 5/" casing, run 4-1/z" 13Cr80 "stacker-packer" completion. MASP: 2270 psi Well Type: Producer Estimated Start Date: April 5, 2008 Production Engineer: Danielle Ohms IntenrentionEngineer: Paul Chan Pre-rip prep work: S 1 Drift thru 4-~/z" tubin for tubin cut. Pull TTP at 8811' MD. E 2 Set 4-~h" HES composite plug at 8817' MD, in the middle of the last pup joint of the tailpipe. CMIT T x IA to 3500 psi. Jet cut 4-~h" 13Cr80 tubing at 8727' MD, 10' in on the first full joint above the Baker SABL-3 acker. Reference tubin tall dated 10/21/92. F 3 Circulate well with kill wei ht fluid and diesel thru the cut. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure „/' 1. MIRU. ND tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~/z" tubing string to the cut. 3. Run USIT log to determine top of cement in 7-5/8' x 10-3/4" annulus. 4. Set retrievable bridge plug 600' below the top of cement and pressure test to 2000 psi for 15 minutes. 5. Cut and pull 7 5/a" casing from above the top of cement. Note: Pipe rams will not be changed to 7- S/e" as the well has two tested barriers (FasDrill plug and RBP) to the reservoir. 6. Run and fully cement new 7 5/s" casing to surface. 7. Run 4-1h" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 8650' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and to to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. TREE= 4-1/16" 5M McEVOY WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 69' BF. ELEV = 3T KOP = 5966' Max Angle = 26 @ 8119' Datum MD = 9123' Datum TV D = 8800' SS -3 3 SAF OTES: "•*cHROnnE TBG ~ LNR'*' 7" TREE CAP 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" ~-~ Minimum ID = 3.725" @ 8811' 4-1 /2" PARKER SWN NIPPLE 4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2944 2871 3 KBMG BK 4 5052 4976 3 KBMG BK 3 6591 6494 19 KBMG BK 2 8141 7889 26 KBMG BK 1 8675 7393 25 KBMG BK 8705 - 14-1/2" PARKER SWS NIP, ID = 3.813" 8763 7-5/8" x 4-1/2" BKR PERM PKR ID = 3.92" 8793 8811 4-1/2" PARKER SWS NIP, ID = 3.813" 4-1/2' PARKER SWN NIP, ID = 3.725" OF 5-1/2" LNR ~-{ 8815' 4-1/2" TBG, 12.6#, 13CR NSCT, .0152 pf, ID = 3.958" 17-5l8" CSG, 29.7#, L-80, 0.0459 bpf, ID = 6.875" I PERFORATION SUMMARY REF LOG: BHCS ON 10/19/92 ANGLE AT TOP PERF: 25 @ 9044' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9044-9084 O 07/03/93 3-3/8" 6 9166-9252 0 01 /06/92 PBTD -~ 943Q, 5-1 /2" LNR 17#, 13CR FL4S, .0232 bpf, ID = 4.892" 9510' 8~ 824' 1~4-1/2" W/LEG, ID= 3.958" 8826' ELMD TT LOGGED 12/31 /92 9199 H JUNK 4-BLADES FROM SWS, FULLBORE SPINNER DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/92 ORIGINAL COMPLETION 07/13/06 TEL/PJC SET4-1/2" PXN PLUG 03/05/08 GJF/SV PULLED PXN PLUG (03/04/08) PRUDHOE BAY UNff WELL: S-33 PERMIT No: 92-1020 API No: 50-029-22293-00 Sec. 35, T12N, T12E BP Exploration (Alaska) 8' TREE = 4-1/16" 5M McEVOY WELLHEAD - FMC - P ti d C ACTUATOR= ~~ OTIS ~ ropose ommo on KB. ELEV = (i9' BF. E1EV.- 37~ Surface TOP OF CEMENT KOP = 5966' Max Angle = 26 @ 8119' Datum MD = 9123' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" Minimum ID = 3.725" @ 8811' 4-1/2" PARKER SWN NIPPLE .. fyts x Nir, iu = s.tsi GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 4 3 2 1 J~ 4-1 /2" HES 'X' NIPPLE, ID = 3.813" I -8650 7-5/8" x 4-1/2" BAKER S-3 PKR 4-1/2" HES 'X' NIPPLE, ID = 3.813" UNIQUE MACHINE OVERSHOT 8705' 4-112" PARKER SWS NIP, ID = 3.813" 8763' H 7-5/8" x 4-1/2" BKR PERM PKR, ID = 3.92" 8793' 4-1/2" PARKER SWS NIP, ID = 3.813" TOP OF 5-1/2" LNR 8815' 8811' 4-1/2' PARKER SWN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, NSCT 13CR 0.0152 bpf, ID = 3.958" 8824' 8824' 4-1/2" WLEG 86-1 ELMD TT LOGGED 12/31/92 17-5/8" CSG, 29.7#, L-80, 0.0459 bpf, ID = 6.875" I I 9018' I PERFORATION SUMMARY REF LOG: BRCS ON 10/19/92 ANGLE AT TOP PERF: 25 @ 9044' Note: Refer to Production DB for historical oerf data S¢E SPF INTERVAL Opn/Sqz 3-3/8" 3-3i8" 4 6 9044-9084 9166-9252 C C 07/03/93 01/06/92 PBTD I~ g430' II S-1/2" LNR, 17#, 13CR, FL4S, 0.0232 bpf, ID = 4.892" I 9199 HJUNK 4-BLADES FROM SWS, FULLBORE SPINNER DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/92 ORIGINAL COMPLETION 07/13/06 TEUPJC SET 4-1/2" PXN PLUG PRUDHOE BAY UNff WELL: S-33 PERMff No: 92-1020 API No: 50-029-22293-00 Sec. 35, T12N, T12E BP Exploration (Alaska) Page 1 of 2 • • Maunder, Thomas E (DOA) From: Chan, Paul (PRA) [Paul.Chan@bp.com] Sent: Thursday, April 03, 2008 4:59 PM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: PBU S-33 (192-102) Trm I have limited knowledge on the 5-33 well after reviewing the drilling file. The OA was freeze protected with dead crude after the 7-518" casing was cemented.. There is a known surface casing leak. The amount of fluid collected from the 1/2 drum ranges from two drops (3/8/08) to ~1 cup/day. There is no data, such as a casing inspection log, on the condition of the surface casing other than the leak that has been re~or~ked. The barriers to the reservoir will be tested production casing (3500 psi test 3/12108), tested tubing tailpipe (3500 psi test i/12108), and a tested. R BP set during the. K~'O, there will not be a barrier in the OA. Please contact one if there are any fitrther questions. T`hankr. Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) '~6~~ C~~R ~ 20~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 18, 2008 2:24 PM To: Chan, Paul (PRA) Cc: Hubble, Terrie L; ]im Regg Subject: RE: PBU S-33 (192-102) Paul, With regard to the "barriers" proposed for the well, the plugs will be tested when installed. What about the OA? Is there any information regarding the condition of the surface casing? Jim located an email from one of the Inspectors in mid-February 2005 where bubbling in the S-33 cellar was noted while the well was on production. Look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 9:34 AM To: 'Chan, Paul (PRA)' Cc: 'Hubble, Terrie L' Subject: PBU 5-33 (192-102) 4/3/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 26, 2008 3:45 PM To: 'Chan, Paul (PRA}' Subject: RE: PBU S-33 (192-102) Are you still working on the barrier stuff discussed in my 2"d message of March 18? Tom Maunder, PE AOGCC From: Chan, Paul (PRA) [mailto:Paul.Chan@bp.com] Sent: Wednesday, March 26, 2008 1:24 PM To: Maunder, Thomas E (DOA) Subject: RE: PBU S-33 (192-102) Tom. The pad engineer did a review and this is her comment: "there is no activit<~ that he would have gotten Sundries for. The only wellwork performed during that period was surveillance work (PPROF's, SBHP, tags) and GL work." Thanks Paul Chan intervention Engineer BP Alaska/wells Group (907) 564-5254 (907} 440-0183 (cell) (907) 564-5510 (fax) From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, March 18, 2008 9:34 AM To: Chan, Paul (PRA) Cc: Hubble, Terrie L Subject: PBU S-33 (192-102) Paul, I am reviewing the sundry. In checking the file, there is quite a gap between setting the TP plug in September 2006 and the March 1996 404 reporting the stimulation of May 1995. Was there any other well work in that time? Just checking to have as complete a file as possible. Thanks, call or message with any questions. Tom Maunder, PE AOGCC 3/26/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 26, 2008 1:56 PM To: 'Chan, Paul (PRA)' Subject: RE: PBU S-33 (192-102) Thanks From: Chan, Paul (PRA) [mailto:Paul.Chan@bp.com] Sent: Wednesday, March 26, 2008 1:24 PM To: Maunder, Thomas E (DOA) Subject: RE: PBU S-33 (192-102) Tom The pad engineer did a review and this is her comment: "there is no activity that he would have gotten Sundries for. The only wellwork performed during that period was surveillance work (PPROF's, SBHP, tags) and GL work." Thanks Paul Chan intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 18, 2008 9:34 AM To: Chan, Paul (PRA) Cc: Hubble, Terrie L Subject: PBU S-33 (192-102) Paul, I am reviewing the sundry. In checking the file, there is quite a gap between setting the TP plug in September 2006 and the March 1996 404 reporting the stimulation of May 1995. Was there any other well work in that time? Just checking to have as complete a file as possible. Thanks, call or message with any questions. Tom Maunder, PE AOGCC 3/26/2008 Page 1 of 2 • • Maunder, Thomas E (DOA) From: Chan, Paul (PRA) [Paul.Chan cr bp.com] Sent: Friday, March 21, 2008 10:10 AM To: Maunder, Thomas E (DOA) Subject: RE: PBU S-33 (192-102) Tom Still working on this. The well has been rescheduled to mid-May. Will try to have something to you by next week. Thanks Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 18, 2008 2:24 PM To: Chan, Paul (PRA) Cc: Hubble, Terrie L; Jim Regg Subject: RE: PBU 5-33 (192-102) Paul, With regard to the "barriers" proposed for the well, the plugs will be tested when installed. What about the OA? Is there any information regarding the condition of the surface casing? Jim located an email from one of the Inspectors in mid-February 2005 where bubbling in the S-33 cellar was noted while the well was on production. Look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 9:34 AM To: 'Chan, Paul {PRA)' Cc: 'Hubble, Terrie L' Subject: PBU S-33 (192-102) Paul, I am reviewing the sundry. In checking the file, there is quite a gap between setting the TP plug in September 2006 and the March 1996 404 reporting the stimulation of May 1995. Was there any other well work in that time? Just checking to have as complete a file as possible. Thanks, call or message with any questions. Tom Maunder, PE 3/25/2008 • • PBU_s-33_Cond_leak_2005-0215_lg.txt subject: 5-33 conductor leak From: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> Date: Tue, 15 Feb 2005 08:02:51 -0900 To: Tim Regg <jim_regg@admin.state.ak.us> Hi Tim, yesterday during svs tests on PBU s pad I observed bubbling and what appeared to be crude/diesel coming from the top of the conductor on 5-33 (PTD# 192-1020). There was a DHD hand (Mel Iverson ) on another well at s pad. Mel came over and looked at this and we agreed the well needed to be shut-in. The gas lift was shut-off and they flowed the well down and I presume it was shut-in and freeze protected. I am leaving today and have not followed up on this. Mel told me this had been identified before and was being evaluated for a variance. on another s pad note, it was blowing to hard yesterday to take pictures but from what I could see there were no sagging flowlines in that bad area I noted before. There is much of activity on the pad but none in that area. when the weather clears it may be a good idea to go back and take a look. Lou Page 1 " STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA TIONSI & Gas Cons. Commission . 1)2$/oc RECEIVED .. . , 1. Operations Performed: u AbandonD Repair WellD Plug PerforationsD Stimulate 0 OtherŒJSecure Well Alter Casing 0 Pull TubingD Perforate New Pool 0 waiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 192-1020 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22293-00-00 7. KB Elevation (ft): 9. Well Name and Number: 69.00 5-33 8. Property Designation: 10. Field/Pool(s): ADL-028257 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9510 feet true vertical 9231.0 feet Plugs (measured) 4-1/2" PXN Plug set@ 8811 (07/13/2006) Effective Depth measured 9430 feet Junk (measured) Fish @ 9199 --- Spinner Blades true vertical 9146.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 35 - 111 35.0 - 111.0 1490 470 SURFACE 2924 10-3/4" 45.5# NT-80 34 - 2958 36.0 - 2958.0 5210 2480 PRODUCTION 8985 7-5/8" 29.7# L-80 33 - 9018 33.0 - 8774.0 6890 4790 LINER 695 5-1/2" 17# 13Cr80 8815 - 9510 8589.0 - 9221.0 7740 6280 ·tjeANNE~)) S E P 2 ¡:"'; Perforation depth: !J Measured depth: 9044-9084,9166-9252 True vertical depth: 8797-8834,8908-8987 Packers & SSSV (type & measured depth): 7-5/8" Baker PERM Packer @ 8763 4-1/2" Otis SSSV Nipple @ 1970 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft SEP .2 (1 2006 Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI 0 0 -- --- Subsequent to operation: 51 0 0 --- --- 14. Attachments: 15. Well Class after proposed work: ExploratoryD Developmentl!! ServiceD Copies of Logs and Surveys run_ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 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 DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer AI ...,../ .;A:~{j Signature L rn ..",-- Phone 564-5174 Date 9/21/06 rrR . ¡ ¡ -, I Form 10-404 Revised 4/2004 U \GI1~J-\ " . . 5-33 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/10/2006 T/IAlOA = SI/450/150 (Pre Rig Workover Inspection) PPPOT-IC = Passed PPPOT-T = Passed Bled Inner casing hanger packoff void to 0 psi. Torqued lockdown screws to 500 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up packoff void to 3,800 psi for 30 mins. - Passed Bled tubing hanger void to 0 psi. Torqued lockdown screws to 500 ft/lbs. Rigged up test equipment, pumped until clean fluid returns were achieved. Pressured up tubing hanger void to 5,000 psi. for 30 mins. - Passed. 08/28/2006 T/I/O = ??/380/80. Temp = SI. WHPs (eval cellar liner removal). Master valve shut (wing valve not holding pressure). 10+ gallons of crude in cellar. Cellar liner appears to be doing its job. 07/31/2006 T/I/O=280/360/70, Temp=SI. Monitor WHP's (post bleed for secure). TBGP decreased 170 psi, lAP remained unchanged, OAP increased 30 psi from 7-30~06. 07/30/2006 T/I/O=790/1080/80. Temp=SI. Bleed WHP's < 500 psi. (For Secure). TBG FL @ 5203' between sta#4 & sta#3 (80 bbl). IA FL @ 6591' sta#3 (173 bbl). Bled lAP from 1080 psi to 370 psi in 1 hour 45 minutes. Bled TP from 790 psi to 450 psi in 1 hour 30 minutes. OAP decreased 40 psi to 40 psi during lAP bleed. Valve crew serviced wing valve and IA casing valve. AL line pressure @ 1500 psi, IA caseng valve is holding. Monitored for 20 minutes during rig down, No change in pressures during monitor. Final WHP's=450/370/40. 07/14/2006 TAGGED XN NIP WI 2' STEM, 3.80" CENT, SAMPLE BAILER @ 8792' SLM, SAMPLE BAILER EMPTY. SET 41/2" PXN PLUG BODY @ 8790' SLM. SET PRONG (1 3/4"-FN, 1.80"- BODY 00, 96"- OAL) @ 8788' SLM, TIIIO- 2000/155010 WHEN SET. BLED T/I/O- 500/120010, WATCH FOR 15 MIN, GOOD TEST. ** TURNED WELL OVER TO PAD OP, LEFT SHUT IN** 07/13/2006 ** WELL SHUT IN UPON ARRIVAL ** {secure well} DRIFTED WI 2' STEM, 3.80" CENT, SAMPLE BAILER. 03/29/2006 T/I/O= 2060/1150/90. Temp= SI. WHP's Open SSV (for secure) call in. FLUIDS PUMPED BBLS I o No Fluids Pumped o ,TOTAL Page 1 I TREE = 4-1/16" 5M McEVOY WELLHEAD = FMC ACTUA TOR = OTIS KB. ELEV = 69' BF. ELEV = 37' KOP = 5966' Max Angle = 26 @ 8119' Datum MD = 9123' Datum TV D = 8800' SS 5-33 SAFETY NOTES: "'CHROME TBG & LNR'" 7" TREE CAP . 1970' -14-1/2" OTIS SSSV NIP, ID - 3.813" I Minimum 10 = 3.725" @ 8811' 4-1/2" PARKER SWN NIPPLE ST MD TVD 5 2944 2871 4 5052 4976 3 6591 6494 2 8141 7889 1 8675 7393 GAS LIFT MANDRELS DEV 1YÆ VLV LATCH PORT 3 KBMG BK 3 KBMG BK 19 KBMG BK 26 KBMG BK 25 KBMG BK DATE 110-3/4" CSG, 45.5#, NT-80, ID = 9.953" H 2958' TOPOF 5-1/2" LNR I 8705' -14-1/2" PARKER SWS NIP, ID = 3.813" I - 7-5/8" x 4-112" BKR ÆRM PKR, ID - 3.92" I -14-112" PARKER SWS NIP, ID - 3.813" I -14-1/2' PARKER SWN NIP, ID = 3.725" -4-1/2' PXN PLUG (07/13/06) I I 7-5/8" CSG, 29.7#, L-80, 0.0459 bpf, ID = 6.875" I 14-1/2" TBG, 12.6#, NSCT 13CR, 0.0152 bpf, ID = 3.958" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/19/92 ANGLE AT TOP ÆRF: 25 @ 9044' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz 3-3/8" 4 9044-9084 C 07/03/93 3-3/8" 6 9166-9252 C 01/06/92 -1 JUNK 4-BLADES FROM SWS, FULLBORE SPINNER PBTD I 9510' 9430' 15-112" LNR, 17#, 13CR, FL4S, 0.0232 bpf, ID = 4.892" I DA TE REV BY COMMENTS 11/06/92 ORIGINAL COMPLETION 07/13/06 TEL/PJC SEf 4-1/2" PXN PLUG DATE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: S-33 ÆRMrr No: 92-1020 API No: 50-029-22293-00 Sec. 35. T12N, T12E BP Exploration (Alaska) TREE= 4-1/16"5MMcEVOY A~TOR -- OTIS '" 'KB. ELEV 69' BE ELEV = 37' -- "' ~ KOP = 5966~ Max An~!le = 26~ ~o. ~ - - -I ~7o. I-H-~,~. o~s sssv ~,,~ = ~.~,, I Datum MD = 9123' Datum TVD = 8800' SS I la GAS LIFT MAI~DRB_S I~o-~.-c~, ~.~. ~-~o,,~=~.~,, H ~"~' k ST ~ ~v~ ~v ~ v.v ~c..o.~ ~T. 5 2944 2871 3 KBIVIG BK [.----- 4 15052 4976 3 KBMG ~ BK Minimum D = 3.725" @ 8811' 3 ;6591 6494 19 KBMG BK 2!8141 7889 26 KBMG BK 4-1/2" PARKER SWN NIPPLE 1.~_ 8675 739.~.3 2.~_5 KBMG ~ BI( ~ ~ i I I-- ~1 8?os' H4-,/~' ~AR~ERSWS N,~, ~--3.813" I I I-- ~t 87*a' H4.~/2, PARKERSWS N,P. D=3.813" I ITOPOFS-1/2"LNRH 8815' I~ ~, ~-~,~..~.~.~#.~o~0,.o.o~¢,,o=~.~.. H 88~4' t-~ ~-~t ,8~4' I-H-~,~'w,~I I 8826' lq ELMD TT LOGGED 12/31/92 , [1 PERFORA'I'ION SUMM~ RY [1 F~F LOG: BHCS ON ~ 0/~ 9/92 ANGLEATTOP PBRF: 25 @ 9044' Note: Refer D Production DB for historical perf data i SIZE SPF INTERVAL Opn/Sqz 3-3~8" 4 9044-9084 O 07/03/93 3-3/8" 6 9166-9252 O 01/06/92 '~--I oao*' ]--I~mK4-~LAmS[ROMSWS, mLL~ORESP~NER 5-~/2" LNR, 17#, ~3CR Ft.4S, 0.0232 bpf, ID: 4.892" Id 05~0' I DATE REV BY COMrvENTS DATE REV BY COMMENTS PRUDHOEBAY UNIT 11/06/92 ;ORIGINAL COMPLETION WELL: S-33 03/09/01 SIS-MH~, ,C...,.CA!VERTEDTO CANVAS PERMIT No: 92-1020 03/12/01 SIS-MD FINAE'''''''"'~ APl No: 50-029-22293-00 091(~/70-~ ""1~1~ CO]~L~"f11~I~ I Sec. 35, T12N, T12E ' BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz 3-3/8" 4 9044-9084 O 07/03/93 3-3/8" 6 9166-9252 O 01/06/92 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/92 ; ORIGINA L COMPLETION 03/09/01 SlS-MH~, .,C,..,.ON. VERTEDTO CANVAS 03/12/01 SIS-MD FiN/~E o 9 / d ¢/b-f ""1~ / ~ SCANNEE; ~AY ~ 0 2003 ANNULAR INJECTION DATA ENTRY SCREEN Asset .~.Q~ .......................................... Rig Name N.~,b.Qr.~..2.8.F,, ............................. Inj Well Name ~.:.3.~ ............................................ Legal Desc .I..6.3.9.'.~.blI,,...I,.4~Z'.~.E,L,..~.eg..;~,5.,.TJ.2,bI.,.BJ.2E .................................. Research ....................................................................................................................... G ~J:.r.e.~t.~.d..~.Q p.y..~.e, ot,.t~.AQ.G.C.G.2.:2.6 :.9.~. ......................... ~ Permit Start ........ J.2[J../.~.~ ........ Permit End ........ .1.~.1/.0..~. ........ ~ Sur Csg Dep 2.9.5..8. ................ Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash FlUids Fluids Freeze Freeze ........ 1.~.,0.1..4 ................. .6 , .6. .1. ~. .................. 2,4.3.1 ................... .~.,3.9.;~ .................................................. 27.0 ...................... 3.0.~. .......... S~29A DaSd 01/18/96 S-29A 01/21/96 S-29A 01/22/9'6 Mud, f.,"tgs, cmt' , Core.ed 3,315 · Daily Data I~ Fnal RigWash ~ F~ Freeze Freeze Daiy ....................................................................................................................................................................564 270'~ .............................................. ~ .................................. ~';'~'~ ......................... 20 160 100 280 35 950 985 66 66 S-,29A 01/23/96 545 45 590 S-29A 01/24/96 100 26 126 '~ /~ --- ' {~4 - ' 604 ..,S_ :_2.. ~ .*_. ............. /.0.~!72(?? I : Open 1992 Year End Summary · ~':~-~ ...................... ')'~'~7~- .............. ] ........................................ t ............................ ~ .............................. "1 ................................................................ ] ........................ §:E~, ..................... ~?~?~-~ ......................................... EE~ ..................................................................................................... ~'6 ......... E~ ................. . .......................... S-29A 102/08/96 I I I '§':'E'~';~ ......................... liSE~i"i~)~ J J li~'~ 1 ! ! / S-29A 1~-2/!3/96 40 100 10 -~50 5:2~, ......... 102/14/96 173 173 §~§~, ........................ ~ ~'~'~2~ .............................. 75 ....................................................................................... ~8 ....................................................................................................................................................................................................................... S-29A 0~17/96 60 60 S-29A 0~19/96 182 756 938 ~S-29A 0~20/96 1,004 1,004 S-29A 0~21/96 ~25 924 949 S-29A 0~2~96 418 418 S-29A ~/96 171 120 291 - . , , , L~ r. ~..... ~ ,~ .... -.-- .................................................................................................................................................................. ........................................................................................................................... ~ ................... ; ....... : ......................................................... : ...................................................................................................................................................................................... ................................................................................................................................................................................... , ...... ~ ............................................................................................................................................................................. ............................................................................................................................................... .............................................................................................................................................................................................................................................................. ....................................................................................................... , .............................................................................................. ared rvices rilling Alaska i 900 East Benson Boulevard, MB 8-1 - Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Annular Disposal Information Request Dear Ms. Mahan: RECEIVED DEC 14 19 8 Naska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispOsal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/31-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-Oi, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42,'S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (1.0-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: NOV I 2002 .Annular Disposal Letter 12/14/98 · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - ~,~oo ~4 ,,-~ ' - · Mi~e Point wells F-06, H-05, H-06, J'13, L-24 - · PBUwells-18-30, 18-31, 14~,~-43, E-34, E-36, G-~A, andS-33-~'~°~ · ~dividufl logs me provided to you for thesb ~ogs tis we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, . Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT CC: Dave Wallace - HSE Manager (w/out attachments) · ~GANNED NOV I Z 200~ RECEIVED !4 1998 ~ask~ 0ii & Gas Cons. Anchorage f. harcd SerVice Drilling nni:{rar Injection Volumes Ldy 25, 1995 until December 1998 umulative Report Surface ,. Casing ) Inj Well Depth Legal Desc dicott yon 15 1-19/I-18 5000 yOn 15 1-23/O-15 4246 i/on 15 1-33/M-23' 5013 Cum Total Cum Mud & Ctgs Sec. 36, T12N, R16E 8,960 7,848 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 Cum Rig Wash Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Fluids Fluids .F[eeze . Freeze Start End S!atus . 992 1,160 150 120 12/5/95 12/5/96 Open 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached ~on 15... 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open /on 15 2-40/S-22 4531 2020'FNL;.2289'FEL Sec 36,T12N, R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 Open A ton 14 15-47 3515 3648'NSL, 4956'WEL, Sec 22 TllN R14E 3 002 903 2 009 ' ' 90 11/7/95 12/31/95 Open ,on 14 DS 15-45 3829 4749' NSL 5180' WEL Sec 22 T11N 1 882 1 697 134 51 4/4/96 4/4/97 Broached ,on 14 DS 15-48 . 3548 Sec. 22, T11N, R14E . 3 385 216. 820 2,283 66 12/21/95 12/21/96 Open 'on 14 DS 15-49 3667 4676' NSL, 5165' WEL Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open 'on 9 18-30 3930 1499'SNL 26'WEL Sec 24 T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 Open on 9 18-31 3680 3719'NSL 64'WEL Sec 24 T11N R14E 6 086 2 250 I 100 2 565 171 7/26/95 12/31/95 Open on 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E . 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open ors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12./31/95 Open ors 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open 3rs 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open Iorafion 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e -' MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open )rs 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open )rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open ~rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open irs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page I Sha.r~d oervice Drilling AnnUlar Injection Volumes July 25, 199~ until December 1998 Cumulative Report Rig Inj Well' ~labors 22E MPF-06 ~labors 22E MPF-14 ~labOrs 22E MPF-70 ~abors 22E MPH-05 Surface Casing ' ' Cum Mud Cum Rig Cum Compl Cum Form Cum Interm. Cum Final Disposal Period Depth Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze ..... Ereeze Start , End, 8766 Sec 06,T13N, R10E 1,927 1,731 196 1/25/96 1/25/97 6690 Se~.'..05.,?13N, R10E. UM 18,717 17,107 1,270 340 6/3/96 ......... 7919 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 190 56 6/17/96 6/17/97 5335 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Annulus Status Open Open Open Open ~abors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open labOrs 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 ' 70 9/21/95 12/31/95 .Open ~ab°rs 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open Jabors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 Open labors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 Open , labors 27E MPF-25 3405 1857'NSL 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open labors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open labors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open abors 27E MPF-45 6678 1979'NSL 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open abors 27E MPF-53 6750 2028'NSL 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open abors 27E MPF-61 6585 2077'NSL 526'WELl Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 Open a.b..o...r..s.....2. ,7.E. .................... .M.~.F_.-...6_2' .................... ..6.?..9. .............................. 2..!...4-1.1..N._S.L 2___ .6_2..7.1. _W_E.L_ L.S...e.c._6.,..T..1..-3...N.L.R. 1_ .0..E" ........................... .3_8...6. ................................... ..3._1_6.. ...................................................................................................... __7_0___1.?_/]..3../_9.?. .......... 11_ ~31./_9.5_ __ ____O p e___n_ abors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 9;665 . 75 8/31/95 12/31/95 Open abors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open abors 27E MPL-24 6515 3654'NSL 5180'WEL, Sec 8,T13N, R10E 6,790 4 900 1,320 165 335 70 11/27/95 12/31/95 Open ~OA IE F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open IE F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/95 12/18/96 Open )yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open )yon 9 D-31 3215 SEC. 28, T11N, R13E . 150 ' 150 4/20/96 4/10/97 Open )yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open Ibors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 · 5/7/98 OPEN Page 2 Shared Sei~ice Dr..illing Annlii~'r injeCtion Volumes July 25, 1995, until December 1998 Cumulative Report Sudace Casing Rig Inj Well Depth Nabors 28E B-33 3504' · Nabors 28E E-34 3664 Nabors 28E E-36 3648 ,. Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum -!-0t~!, & Ctgs W~!sh Fluids Fluids Freeze Freeze Start End. Status 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 Broached 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open ; 1706'SNL, 8221WEE, Se~ 6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open Nabors 28E 'E-37 3810 3391'NSL 881'WEL Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open ................................................................................ ...__~ '~-1 .... 1. ........................................................... ..:- ........................................... ~ ...................................................... Nabors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,111N R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors28E G-O4A 3509 2917'NSL, 1974'WEL, Sec 12,T11N R13E 5,937 1,798 1,824 2,315 10/20/95 ,12/31/95 Open Nabors 28E G-21 3509 2911'NSL, 2368'WEL, Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 70 '62 9/8/95 12/31/95 O3en Nabors 28E S-24 2750 1633'SNL 4228'WEL, Sec 35,T12N, R 12E 20,261 11,773 2,177 ' 5,751 '275 285 12/9/95 12/9/96 O ~en Nabors 28E S-33 2958 1639'SNL 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 O3en Nabors 28E S~41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4 159 2,034 1,754 115 2/8/96 . 2/8/97 O 3an Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 O3en qabors 2ES H-35 3157 4535'NSL 1266'WEL, Sec 21 T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 ' 12/31/95 O ~en qabors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 O3en Page 3 hcared orr. ices riliing TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: APl # MPB-24 Well Suspension 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid wastes. There are no other well annulii on this pad for injection.. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 , i STATE OF ALASKA KA OIL AND GAS CONSERVATION COMMISo',ON 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 BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1639' SNL, 1487' EWL, SEC. 35, T12N, R12E At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=69 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-33(11-35-12-12) feet 9. Permit number/approval number 826' SNL, 4836' WEL, SEC. 35, T12N, R12E At effective depth 810' SNL, 4896' WEL, SEC. 35, T12N, R12E At total depth 783' SNL, 5001' WEL, SEC. 35, T12N, R12E ORIGINAL 10. APl number 50- 029-22293 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9510 feet Plugs (measured) 9231 feet 9430 feet Junk (measured) 9146 feet Casing Length Size Structural -- Conductor 110 20 Surface 2927 10 3/4 Intermediate 8981 7 5/8 Production -- Liner 674 5 1/2 Perforation depth: measured 9192'- 9252' Cemented 11 yds Arcticset 1794/404 c.f. AS III 303 c.f. Class "G" 122 c.f. Class "G" true vertical subsea 8930'- 8985' Measured depth 143 2959 9018 8834-9508 True vertical depth BKB 143 2959 8776 8607-9230 Tubing (size, grade, and measured depth) 4 1/2" 13CR @8824' Packers and SSSV (type and measured depth) Packers @8763' & SSSV @ 1970' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 950 625 521 2070 991 423 542 1940 Tubing Pressure 205 191 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 ce~ that the f,,orjegoing is tru,¢, and correct to the best of my knowledge. S igned,"~~~~~~ Title Technical Assistantlll Form 10-404 Rev 06/15/88 Date~:>//~/~~:~ SUBMIT IN DUPLICATE WELL S-33(11-35-12-12) Stimulation Operation 5/5/95 A Packer acid Treatment was performed using the following fluids: OPERATIONS SUMMARY TIH W/BHA #1. LOAD WELL WITH 150 BBL SW WITH SUFACTANT AND SLICKEM. TIE INTO ELMD WITH XN NIPPLE. SET PACKER AT 9130'. PUMP SW DOWN BACKSIDE WHILE PUMPING ACID DOWN COIL. INITIALLY INJECTING 3 BPM AT 3000 PSIG COIL PRESSURE. FINAL ACID INJECTED AT 3 BPM AND 1960 PSIG COIL PRESSURE. POOH WITH ALL BHA. FLUIDS PUMPED BBLS. 300 168 35 DESCRIPTION FILTE~D SEA WATER W/0.2% SURFACTANT 7.5% HCL W/0.5% ACI-274, 1% HYTEMP-382, 0.6% NE-41, 0.2% MS- 10, 0.06 % AG-12, 50 #/TG FE-300, 20 #/TG FE-210 METHANOL LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1995 RE: Transmittal of Data Sent by~ PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 6' 5 q~ /~:~ ,.,~,~:'. S-33 (11-35-12'12) x-0 DESCRIPTION CCL/CUT FINAL BL+RF PLS/STATIC FNL BL+RF PLS/STATIC FNL BL+RF ECC No. Run ~ 1 4030.01 Run # 1 ' 5750.10 Run # i 6234.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B' Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please reign and retur~ Petro2eohntoal Data Cente~ BP ExploratiOn (Alaska) In~ ~00 East~son Boulevard .... ' ...... ~AY 04 1995 Alaska 011 & Gas Cons. Commission Anchorage ANNULAR INJECTION DATA ENTRY SCREEN A s s e t .WO&. ......................................... Rig Name .blab~r.s.2.SE ........................... Inj Well Name iS.=331.~i. .................................... Permit Start ..... .l.2./..1J.~t.5 ..... Sur Csg Dap 2.9.51~ .............. · .............................. .... 1.~]..1.~/..9.2... Cumulative Data Legal Desc .1B2[g.'.SI~L...1..4BZ'.WE.L...$~..35.,.T. J2_N,...B.1.2E ..................... Research ....................................................................................................................... .Cc~r.[~cted..c. opy...s~.r,2..t.e...&Q.GC.C..2:2~:95 ............... Permit End ..... .1.2/..1./.9.6 ..... .... 1..t1.1.S/..9.2... Soume Date of Well Injection ................................. ....................................... ~';'~'¥'~ ......................................................... 1 ........................ ~"~'~ ..................... '~:'~"~'~ .............. j'(~'"i"'/~"~}"~'~ ................................ ~'~ ............. I ................................. ! .................................. ~j~ 54-~'~14~ --l---- -- ;:-~;'B~' ........ i'~"i'7~";~'7B"~'"~i'"~'8 ................... ~'~'~- ......... J ..................... j .......................... __ ..S_-29_A_ .... i..0_. !__/_~._5..L._9._~ _1._,_.0__0_0_ _ ~__5 __ j j ~:~'~'~,- .......... j'~'i"~"~-~-/'~-~ ........................ '~-~' ........... i ........................ J ............................... S-29A 01/30/96 359 ~:~.~2.~9~'~..._~,_I 01 / 31 / 96 S-29A !02/01/96 S-29A i02/02/96 S-29A i02/03/96 S-29A i02/04/96 S-29A i02/05/96 S-29A J02/06/96 S-29A j02/07/96 S-29A 102/08/96 S-29A 102/09/96 S-29A j02/10/96 S-29A 102/11/96 S-29A 102/1 2/96 02/1 3/96 S-29A Daily Data iMUd,contaminatedctgs' Cm!j RigWash: I ComPletion Formation il IntermittantFreeze J Free~'e :i DailyFinal {i j AnnUiu~ Drlg MUd F ; ' : lu~ds ;I: Fluids i FlUids ProteCtion::!': Protection i ;;TOtal' :: j :;Rate :j pressurel ;;;;status;;; l: cornrnents Complications 1992 Year End Summary 6O S-29A 128 lOO 225 590 ~126 __ 1,411 896 91 !395 25 1743 ~604 I i136 i110 't--' il0 J235 00 . .................... 110 11o j __j15 J501 ......... i_1__5_ ........ [783 {10 150 40 02/14/96 73 i 173 S-29A 02/1 5/96 75 75 S-29A 02/17/96 60 60 .................. , ............................................ , ................ = ..................................... ~ .................. = .............................................. S-29A 02/1 9/96 182 756 938 S-29A 02/20/96 __ 1_,004 il,004 S-29A 02/21/96 -25 924 i949 S-29A 02/22/96 I 418 ~418 120 291 S-29A O2/23/96 171 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 November 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 cN/GR ZINAL B~, + R~ % ~- ?D Z-14L (44-18-11-13) -/~B-as (22-31-11-14) 0~S-32 (33-26-12-12) 1 PDK FINAL BL + RF 1 PLS FINAL BL + RF 1 PDK BORAX FNL BL+RF 1 CN/GR FINAL BL + RF 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run ~ 1 Run ~ 1 ECC No. 4529.04 4595.07 5833.06 6012.02 6105.02 6107.04 6202.01 Please sign and return to: A~as Wirelin~rvices Suite ~ h/-~n. Roaney u. Fau&son Or FAX to (907) 563-7803 Received by:~ ~~ Date: PERMIT DATA ~OGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 92-102 BHC/SL CNL/GR PDK-100 PDK-100 PFC PFC/GR PFC/GR PIL/SFL PLS PROD SBT SSTVD 407 DAILY WELL OP 92-102 SURVEY 92-102 5444 92-102 5556 92-102 5687 L 9022-9475 L.~8045-9457 L 9000-9270 L 9000-9394 L 8660-9273 L 9000-9200 L 9100-9350 L 9022-9508 L 8900-9168 L 9000-9260 L 8820-9394 L 9022-9506 R COMP DATE: 11/06/92 R 10/05-10/22/92 R 0.00-8592 T 8044-9529 OH/FINALS T 8979-9394 CH/?DK-100 T 8969-9265 CH/PDK-100 Page' 1 Date: 11/02/94 RUN DATE_RECVD 1 10/29/92 1 10/29/92 1 05/12/93 1 01/04/93 1 01/25/93 1 07/12/93 1 11/18/92 1 10/29/92 1 06/03/94 1 03/10/93 1 01/04/93 1 10/29/92 01/19/93 01/19/93 01/19/93 1 11/18/92 1 03/10/93 1 07/06/93 Are dry ditch samples required? yes ~ And received? Was the well cored? yes e~s Analysis & description received? Are well tests required? q~o Received? yes~ Well is in compliance ~~ COMMENTS yes yes .~ STATE OF ALASKA ALAS .... ')IL AND GAS CONSERVATION COMMISSIO'~' ' REPORT Gl-: SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing __ Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 1639' SNL, 1487' EWL, SEC. 35, T12N, R12E At top of productive interval 826' SNL, 4836' WEL, SEC. 35, T12N, R12E At effective depth 810' SNL, 4896' WEL, SEC. 35, T12N, R12E At total depth 783' SNL, 5001' WEL, SEC. 35, T12N, R12E 6. Datum elevation (DF or KB) KBE=69 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-33(11-35-12-12) 9. Permit number/approval number 92-102 / 10. APl number 50- 029-22293 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9510 feet 9231 feet 9430 feet 9146 feet Casing Length Size Structural -- Conductor 110 20 Surface 2927 10 3/4 Intermediate 8981 7 5/8 Production -- Liner 674 5 1/2 Perforation depth: measured 9192'- 9252' Plugs (measured) Junk (measured) Cemented 11 yds Arcticset 1794/'404 c.f. AS III 303 c.f. C/ass "G" 122 c.f. Class "G" Measured depth 143 2959 9018 8834-9508 True verticaldepth BKB 143 2959 8776 860~9230 true vertical subsea 8930'-8985' Tubing (size, grade, and measured depth) 4 1/2" 13CR @8824' Packers and SSSV (type and measured depth) Packers @8763' & SSSV @ 1970' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1740 1150 18 1534 2830 / 220£' 310 1386 Tubing Pressure 251 241 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 foregoin.~, is true and correct to the best of my knowledge. Si~tned ~..~_~, ..'t~.v / L'~.i (~.~-,~-Lg, j.f Title Senior Technical Assistant I Form 10-404 Rev 06/15/88 / Date SUaM~T ~N D6PU(~ATE WELL S-33(11-35-12-12) REPERF/FRAC]ADDPERF 4/20/93 4/28/93 The following interval were reperforated using 3 3/8" guns, 4 SPF, random orientation and 60° phasing. 9166'-9196'MD Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: 250 BBLS 20# GEL DATA FRAC: 20 BBLS 40# GEL PREPAD TO ESTABLISH RATE 150 BBLS 40# X-LINK GEL PAD 134 BBLS 20# GEL DATA FRAC FLUSH 75 BBLS DSL TO FREEZE PROTECT WELL FRAC: 20 BBLS 40# GEL PREPAD TO ESTABLISH RATE 122 59 9 12 14 16 17 17 134 28 42 134 BBLS 40# X-LINK GEL PAD W/500# 100 MESH SAND Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 10PPG 20/40CL 10 PPG 16/20CL 20# LINEAR GEL FLUSH 07/03/93 fjh 6/21/94 The following additional interval were perforated using 3 3/8" guns, 4 SPF, random orientation. 9044'-9084'MD ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 17 May 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION z-as K-10 (31-05-11-14) ~'~--~ J-10 (10-11-13) q~--}lq S-38 (24-26-12-12) q 7-- iQrL s-33 ( 11-35-12-12 ) q~-lq~ s-35 (23-26-12-12-) qL-I I~ s-36 (41-34-12-12) cont/ /~_ PFC/PERF FINAL BL ! PFC/PERF RF SEPIA /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA 1 DIFFTEMP/GR FINAL BL /1 DIFFTEMP/GR RF SEPIA /I PAS FINAL BL 1 PAS FINAL RF SEPIA / PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PLS FINAL BL ! PLS FINAL RF SEPIA ~1 PLS FINAL BL 1 PLS FINAL RF SEPIA .~1 PDK/GR/CCL FINAL BL 1 PDK/GR/CCL RF SEPIA ECC No. Run ~ 1 6196.00 Run ~ 1 Run ~ 1 6162.01 Run ~ 1 Run ~ 1 3556.04 Run # 1 Run # 1 Run # 1 4887.03 Run ~ 1 5840.03 Run # 1 Run ~ 1 5750.09 Run ~ 1 Run ~ 1 5867.05 Run # 1 Run # 1 5788.05 Run ~ 1 Run # ! 5858.05 Run # 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/07/93 T# 84739 BPX/PBUQLOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-40q~'lq P~.~,.F 06/28/93 #1 ~,~ PRODUCTION LOG 06/26/93 #1 N-20 PERF 07/01/93 #1 S-2490-~ PERF s-2590-i~ PERF s-33q%- tO?... PERF S-34 q~.,,w~ PERF s-35 qz-Iq$ PERF S-36 ~%-~ PERF S- 3 8 ~47.- %7.'~ PERF z- 19 Z.Z% 07/01/93 #1 07/01/93 #1 07/03/93 #1 06/30/93 #1 06/30/9:~=.' #1 06/28/93 #1 07/01/93 #1 06/30/93 #1 9200.00-10194.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 9915'.00-10056 00 ATLAS 5 " 9700.00- 9950 00 ATLAS 5 " 9058.00- 9253 00 ATLAS 5 " 900Q,00- 9200 00 ATLAS 5 " 10100.00-10259 00 ATLAS 5 " 9500.00- 9702 00 ATLAS 5 " 9765.00- 9986.00 ATLAS 5 " 9200.00- 9350.00 ATLAS 5 " 13940.00-14224.00 ATLAS 5 " Information Control Well Records RECEIVED JUL 1 2 199 A;aska 0il & Bas Cons. Commission Anchorage BP EXPLORATION '3 "~BP Exploration (Alaska) Inc. ~t00 East Benson Boulevard P.O. Box 196612 ~;Anchorage, Alaska 99519-6612 .07) 561-5111 '? DATE' 06/08/93 T# 84645 BPX/PBU~GNETIC TAPES Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) S-33 CH/PDK-100 FIN 03/28/93 #1 8969.00- 9265.00 1600BPI API#500292229300 9375->TP# CH/PDK-100 FIN 03/27/93 #1 11531.00-11982.00 1600BPI API#500292047401_ 9376->TP# ... If you have any 564-4004. ATLAS REF#5750.06 ATLAS REF#5887.08 Information Control Well Records RECEIVED JUL 0 6 995 Alaska Oil & {~as Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P..O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/27/93 T# 84513 BP/PBU~OGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~ S-33 PFC 04/22/93 #1 PRODUCTION LOG 04/21/93 #1 PFC 04/19/93 #1 PFC 04/20/93 #1 PDK-100 03/28/93 ~1 PFC 04/19/93 #1 10665.00-10901.00 ATLAS 5 " 10900.00-11350.00 ATLAS 5 " 10710.00-11100.00 ATLAS 5 " 9163.00- 9232.00 ATLAS 5 " 9000.00- 9270.00 ATLAS 5 " 9252.00- 9596.00 ATLAS 5 " Information Control Well Records Z BP EXPLORATION RECEIVE,D MAR 1 0 199, ,Naska 0il & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/01/93 T# 84339 BP/PBU MAGNETIC TAPES AND CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 02/11/93 REF#1373.04 02/11/93 REF#1373.04 02/11/93 REF#1373.04 01/13/93 REF#5842.02 12/17/92 REF#5750.01 MAC/GR (LDWG FORMAT); W ATLAS MAC ACOUSTIC FILTERED W ATLAS BOREHOLE COMPENSATED MA ATLAS PDK-100/GR (LDWG FORMAT ATLAS PDK-100/GR (LDWG FORMAT ATLAS Information Services Well Records BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03-03-93 T# 84406 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-07~CH F-39~CH K-06~CH M-31__~_~I~CH N-14 ~ ~._~.~__~~~ CH N-16 CH S-33~CH X-14A~H 02/23/93 REF#124752 02/22/93 REF#124751 02/23/93 REF#124673 02/24/93 REF#124674 02/26/93 REF#124801 02/25/93 REF#124675 02/25/93 REF#124754 02/24/93 REF#124753 PRODUCTION LOGGING sERv ATLAS PRODUCTION LOGGING SERV ATLAS COLLAR LOG (CHEMICAL CU ATLAS PFC GAMMA RAY (PERFORAT ATLAS PFC GAMMA RAY (PERFORAT ATLAS PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS PFC/CCL (PERFORATION RE ATLAS Information Services Well Records MAR 7 0 Alaska Oil & Gas Cons. Commission ';' Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02/11/93 T# 84301 BP/ PBU OH TAPES (REPLACEMENTS) Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) ¢ OH/BHC ~¢~ FIN 10/19/92 #1 8044.00- 9529.50 1600BPI API#500292229300 9138->TP# q '~S'- 3~7~ OH/BHC< ~~ FIN 11/03/92 8079.50- 9779.00 ~ 1600BPI API#500292229100 9145->TP# Information Control Well Records ECEIVED FEB 1 8 A~aska Oil & Gas Cons. Commis~s[o_tl' Anchorage If you have any 564-4004. SCH REF# 92 620 #1 SCH REF#92 662 Please NOTE that these tapes are replacement tapes for previously distributed materials. S-33; replaces tape S-33 which has the GR in casing curve missing and was sent in transmittal #84041 S-37; replaces tape S-37 which had one blank tape in the previous distribution and was sent in transmittal #84085. Because one tape was blank all were redone and are being redistributed. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01-07-93 T~ 84260 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 12/28/92 REFgl14983 12/30/92 REF#124604 12/31/92 REF#114986 12/31/92 REF~124605 12/29/92 REF~124603 12/29/92 REFill4984 PRODUCTION LOGGING INJE COLLAR LOG (PERFORATING PRODUCTION LOGGING INJE PFC GAMMA RAY; PERFORAT PFC GAMMA RAY; PERFORAT CASING COLLAR LOCATOR(T ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS Information Services Well Records CEIVED JAN 2 5 199~ :~,taska Oil & Gas Cons. Commission Anchorage "--" STATE'OF ALASKA ALASKA ,JiL AND GAS CONSERVATION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-i St..ISPEI',IZ)F_D I-! ABANDONED I-1 SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-102 3. Address ~. APl Number 196612, Anchora,.qe, .... 50- 029-22293 P. O. Box Alaska 99519-6612 ~'~i?i':~ ...... 4. Location (~! well at surfacej 19. Unit or Lease Name i ?': .......... Prudhoe Bay Unit 1639' SNL, 1487' EWL, SEC. 35, T12N, R12E - .. i ~ ~ . .,~. ,. At Top Producing Interval ~ ~/~f-~;:~:,- i 10. Well Number .... ~'-~ 11. Field and Pool At Total Depth '"~ i'~"~-.)'fT'~'~ Prudhoe Bay Fie/d/Prudhoe Bay Pool 780' SNL, 331' EWL, SEC. 35, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 69' ] ADL 28257 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offsho r~ J16. No. of Completions 10/6/92 10/18/92 11/6/92I N/Aeet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDi 19. Directional Survey ~>0. Depth where SSSV set ~21. Thickness of Permafrost 9510' MD/9231' TVD 9430' MD/9146' 7'VD YES [] No []~ 1970~eet MD !' 1900'(Approx.) 22. Type Electric or Other Logs Run G R/S P/D //S FL/B H C/ C N L 23. CASING, LINER AND CEMENTING FIECORD SE3Tt, iG DEPTH MD CASING SIZE WT. PER FTi GRADE TOP BOTTOM HOLE SIZE CEMENTI",~ RECORD AMOUNT PULLED 20' 91.5# H-40 Surface 76' 30" 11 yds Arcticset 10-3/4' 45.5# NT-80 36' 2958' 13~1/2" 1794 cu ft AS I///404 cuft AS / 9-7/8' 29. 7# NT95HS 37' 9018' 9-7/8" 303 cu ft C/ass "G" ,,, 5-1/2' 17# L-80 8834' 9508' 6-3/4" 112 cu fi C/ass "G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUB~RECORD interval, size and number) SIZE DEPTH SET(MD/ PACKER SET (MD/ Gun Diameter 3-3/8" 4spf 4-1/2"13CR 8824' 8763' MD TVD 9192'-9252' 8930'-8985' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCT]ON TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11/9/92 I Gas Lift Date of Test Hours Tested IPRODUCTIONFOR OIL-BBL GAS-MCF WATER-BBL CHOKE~ IGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure .~ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. _ Form __ .......... Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,-29. 30. GEOLOGIC MARKERS ~ ,,,, tMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase, Top Sag River 9043' ss 8730' Top Sadlerochit 9165' ss 8843' HOT 8971' ss 8971' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~"~~ TitleOri//inoEnoineorSu.D~rVi~or Date 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 jection, Gas Injection, Shut-in, Other-explain. ~.~.,~ ~. i:.~ ~ Item 28: If no cores taken, indicate "none". "' '~,. :~..~ '~. ~ ~j Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-33 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-22293 PERMIT: APPROVAL: ACCEPT: 10/06/92 12:10 SPUD: RELEASE: 10/21/92 10:10 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 10/05/92 (1) TD: 0'( 0) PREPARE TO MOVE MW: 0.0 VIS: 0 LD DERRICK & PREPARE TO MOVE TO S PAD. 10/06/92 (2) TD: 0'( 0) 10/07/92 (3) TD: 2300' (2300) 10/08/92 (4) TD: 2970' ( 670) 10/09/92 (5) TD: 2970' ( 0) PH BHA MW: 0.0 VIS: 0 MOVE RIG TO S-33. ACCEPTED RIG AT 0001 HRS. 10/6/92. MU RISER. MIX SPUD MUD. PU BHA. DRILLING MW: 9.3 VIS:278 MAKE UP BHA. DRILL & GYRO SURVEY TO 1926' CBU. DRILL TO 2300' RUN 10-3/4 CASING MW: 9.8 VIS:240 DRILL TO 2689' GRYO SURVEYS. DRILL TO 2970'. CIRCULATE. SURVEY. CIRC. POOH. CIRC. POOH. RUN 10-3/4 SURFACE CASING. DRILL OUT 10-3/4 CASING MW: 9.8 VIS: 37 10/10/92 (6) TD: 4971' (2001) 10/11/92 ( 7) TD: 5910' ( 939) 10/12/92 ( 8) TD: 6928' (1018) TRIP FOR BIT %3 MW: 9.9 VIS: 38 PERFORM LOT. DRILL TO 3481'_ CBU. RUN GYRO_ DRILL TO 3977' CBU. WIPER TRIP TO 10-3/4 CASHING SHOE. DRILL TO 4971'. CIRC. TIH. DRILLING MW: 9.9 VIS: 40 TIH. REAM TO 4971' DRILL TO 5640' CBU. DROP SURVEY. TOH. TIH WBIT ~4. DRILL TO 5910' TRIP FOR BIT MW:10.2 VIS: 39 DRILL TO 6928'. CIRCL. DROP SURVEY & PUMP DRY JOB. TOH. 10/13/92 (9) TD: 7753' ( 825) DRILLING TOH. DRILL TO 7753'. MW:10.2 VIS: 40 10/14/92 (10) TD: 8500'( 747) DRILLING AT 8500 MD MW:10.2 VIS: 42 DRILL TO 7940'. DRILL TO 8003' CBU. SHORT TRIP. DRILL TO 8500' W~LL : S-33 OPERATION: RIG : NABORS 28E PAGE: 2 10/15/92 (11) TD: 8950' ( 450) 10/16/92 (12) TD: 9032' ( 82) 10/17/92 (13) TD: 9032' ( 0) 10/18/92 (14) TD: 9170' ( 138) 10/19/92 (15) TD: 9510' ( 340) 10/20/92 (16) TD: 9510 PB: 9430 10/21/92 (17) TD: 9510 PB: 9430 DRILLING AT 8950 MD MW:10.2 VIS: 48 DRIL TO 8500' DROP SINGLE SHOT SURVEY. PUMP DRY JOB. POOH W/BIT. DRILL TO 8950' RIH W/7-5/8 CASING MW:10.3 VIS: 46 DRILL TO 8950' CIRCULATE. SHORT TRIP. CIRCULATE. DROP SURVEY. CIRC. CHANGE TOP RAMS TO 7-5/8'. RIH W/7-5/8 CASING. CBU AT 8105' MD MW:10.3 VIS: 37 RIH W/7-5/8 CASING. LAND CASING AT 9018'. TEST LINES. DROP BOTTOM PLUG. PUMP SPACER. DROP 2ND BOTTOM PLUG. PUMP CLASS G 1.5%D-79 + 0.2% D-46 SLURRY. DROP TOP PLUG. CEMENT IN PLACE. INSTALL & TEST PACKOFF. TEST BOPE. RIH W/3-1/2 DP. CBU. DRILLING AT 9170 MD MW: 9.1 VIS: 41 TEST CASING. CBU. TEST CASING. DRILL FLOAT COLLAR. CIRC & CONDITION MUD. DRILL TO 9170' RD SCHLUMBERGER MW: 9.2 VIS: 42 DRILL TO 9510' CBU. TAKE SURVEY. PUMP DRY JOB. POOH FOR OPEN HOLE LOGGING. RUN #1 GR/SP/DI/SFL/BHC/CNL. MU 3-1/2 BHA FOR CLEANOUT & DT MW: 9.2 RIH F/WIPER TRIP. CIRC. POOH. RUN CASING. RIH W/5-1/2 LINER. BREAK CIRCULATION AT 7-5/8 SHOE. FINISH RIH W/LINER. RECIPROCATE, CIRCULATE & CONDITION. BATCH MIX CEMENT. TEST LINES. PUMP SPACER. FOLLOW W/CLASS G CEMENT. DISPLACE CEMENT. BUMP PLUG. SET HANGER. SET LINER TOP PACKER. RELEASED FROM HANGER. REVERSE OUT CEMENT. PU 3-1/2 CASING SCRAPER. RIH.FREEZE PROTECED W/CRUDE. RUNNING 4-1/2 TUBING MW: 8.5 Seawater TIH. TEST CASING. REVERSE CIRCULATION. TEST CASING. POOH. RUN 4-1/2 COMPLETION. OBM 10/22/92 (18) TD: 9510 PB: 9430 RIG RELEASED MW: 8.5 Seawater RUN 4-1/2 COMPLETION. TEST CONTROL LINES. LAND TUBING. SET PACKER. TEST TUBING. TEST ANNULUS. SET BPV. TEST CONTROL LINES. TEST TREE. PULL BPV. PUMP DIESEL IN TUBING. SET BPV. RELEASE RIG 2200 HRS. 10/21/92. SIGNATURE: (drilling superintendent) DATE: ~.ERRY-SUN DRTLL]'NG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/S-33 500292229300 NORTH SLOPE COHPUTATZON DATE: 10/14/92 DATE OF SURVEY: 101492 HWD SURVEY JOB NUHBER: AK-HW-20080 KELLY BUSHZNG ELEV, = 69,00 OPERATOR: BP EXPLORATZON FT, TRUE SUB-SEA COURS COURSE DLS HEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON RECTANGU DEPTH DEPTH DEPTH DG HN DEGREES DG/IO0 NORTH/S TOTAL LAR COORDZNATES OUTH EAST/WEST VERT, SECT, 0 ,00 -69,00 259 259,00 190,00 607 606,99 537,99 937 936,97 867,97 1453 1452,86 1383,86 0 0 N ,00 E 0 15 S 24,00 E 0 30 S 31,00 E 0 45 S 1,00 E 1 30 S 53,00 E .00 . .10 . ,07 2. ,12 5, ,23 13, OON ,OOE ,00 523 ,23E -.51 513 1,32E -2,62 903 2.10E -5,38 353 7,55E -14,32 1866 1865,55 1796,55 2240 2239,19 2170,19 2629 2627,89 2558,89 2871 2869,66 2800,66 3043 3041,43 2972,43 2 45 S 69,00 E 2 15 S 16,00 E 2 15 S 11,00 E 2 45 S 6,OO W 3 5 S 35,00 W ,33 20, ,61 30, ,05 45, ,37 55, ,87 63, 153 21,12E -29,11 423 31.52E -43,67 263 35,08E -55.86 693 35,38E -62,73 613 32,28E -65,38 3330 3328.01 3259.01 3427 3424.71 3355.71 3618 3615.41 3546.41 3746 3743,35 3674,35 3904 3901,29 3832,29 4 35 N 46.90 4 30 N 39,10 1 47 N 19,60 1 36 N 3,40 1 36 N 4,80 2,05 62, ,65 56, 1,50 47, ,41 44, ,03 39, 103 19,42E -54,50 493 .14,18E -46.88 853 8.44E -36,96 173 7,66E -34,02 773 7.35E -30.98 4095 4092.19 4023,19 4286 4283.02 4214,02 4476 4472.77 4403.77 4759 4755.35 4686,35 4898 4894,15 4825.15 2 0 N ,60 W 2 47 N ,70 E 3 5 N 19.20 W 3 5 N 14,10 W 3 12 N 13,10 W ,22 33, ,42 25, ,56 16, ,10 1 , ,08 5. 783 7,09E -26,96 783 7.11E -21.89 293 5,48E -14,59 643 1.10E -1,89 78N ,70W 4,22 5204 5199,65 5130.65 5459 5454,25 5385,25 5554 5549,08 5480,08 5680 5674,59 5605,59 5775 5769,07 5700.07 3 17 N 25.30 W 3 5 N 40.60 W 3 47 N 39.90 W 6 5 N 43.50 W 5 54 N 54.30 W ,23 22. .34 33, ,74 38, 1,84 46, 1 ,21 52. 06N 6.40W 18,98 93N 14,02W 32,41 30N 17.71W 38,04 36N 25,00W 48,78 87N 32.44W 58,67 5871 5864,45 5795,45 5966 5958,53 5889,53 6030 6021,54 5952,54 6125 6114,60 6045,60 6190 6177,90 6108,90 7 0 N 57,10 W 8 53 N 55.80 W 11 6 N 54,40 W 12 6 N 50,60 W 14 6 N 48,60 W 1 ,19 58, 2,01 66, 3,46 72, 1.32 84, 3,15 93, 93N 41.36W 69,40 20N 52,29W' 82,47 57N 61.40W 93,54 21N 76.53W 112.62 77N 87,73W 127,35 6286 6270,92 6201,92 6413 6393,56 6324.56 6540 6514,87 6445,87 6603 6574,44 6505,44 6698 6663.46 6594,46 14 30 N 50,00 W 15 36 N 48,50 W 18 47 N 45,80 W 19 12 N 47,10 W 21 36 N 49,50 W ,55 109, ,92 130. 2,60 156, ,92 170. 2.67 192, 23N 105.71W 151,05 77N 130.68W 184,02 36N 158,15W 221,49 48N 173.01W 241,95 47N 197.75W 275,03 SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA .... -. PAGE 2 PRUDHOE BAY DRZLLZNG PBU/S-33 500292229300 NORTH SLOPE CONPUTATZON DATE: 10/14/92 DATE OF SURVEY: 101492 HWD SURVEY JOB NUHBER: AK-NW-20080 KELLY BUSHZNG ELEV, = 69,00 OPERATOR: BP EXPLORATZON FT, TRUE SUB-SEA HEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL ZNCLN DZRECTZON RECTANGULAR COORDZNATES VERT, DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT, 6?92 6750,29 6681,29 23 23 N 48,30 W 1,98 216,13N 224,85W 310,98 6855 6808,04 6739,04 23 42 N 49,30 W ,79 232.71N 243,78W 336,14 6983 6924,84 6855,84 24 36 N 47,20 W ,97 267,58N 282,84W 388,46 7142 7069,35 7000,35 24 42 N 47,90 W ,19 312,34N 331,77W 454,68 7428 7330,00 7261,00 23 53 N 49,90 W ,40 389,72N 420,42W 572,31 7711 7588,74 7519,74 23 53 N 48,50 W ,20 464,63N 507,21W 686,93 7930 7787,73 7718,73 25 30 N 55.10 W 1,45 521,01N 579.11W 778,28 8119 7958,11 7889,11 25 47 N 53,60 W ,38 568,70N 645,58W 859.90 8277 8100,83 8031,83 25 0 N 57,80 W 1,25 606.89N 701,51W 927,34 8498 8300,96 8231,96 25 12 N 60,60 W' ,55 654,87N 782.02W 1019.98 8592 8386.22 8317.22 24 36 N 62.20 W .96 673.82N 816.76W 1058.83 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZNENSZON NZNZNUH CURVATURE METHOD, HORZZONTAL DZSPLACEMENT = 1058,83 FEET AT NORTH 50 DEG, 28 NZN. WEST AT ND = 8592 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 309,52 DEG, .S~....~PERRY-SUN DRILLING SERV]'CES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/S-33 500292229300 NORTH SLOPE COMPUTATTON DRILLING DATE: 10/14/92 DATE OF SURVEY: 101492 JOB NUMBER: AK-MW-20080 KELLY BUSHING ELEV. = 69,00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -69,00 .00 N .00 E 1000 999,96 930,96 6,73 S 2,11 E 2000 1999,40 1930,40 22,45 S 27,12 E 3000 2998,50 2929,50 61,70 S 33,62 E 4000 3997,25 3928,25 37,09 S 7,12 E ,00 ,04 .04 ,60 ,57 1 ,50 ,9O 2,75 1 ,25 5000 4995.99 4926.99 11.33 N 1.99 6000 5992.10 5923,10 69,21 N 56.70 7000 6940.30 6871.30 272,39 N 288,03 8000 7850,91 7781.91 538.26 N 603.83 8592 8386.22 8317,22 673.82 N 816.76 4.01 1.27 7.90 3.88 59.70 51.81 149.09 89.38 205.78 56.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIHENSION NZNZNUM CURVATURE HETHOD, · PAGE 4 SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA .... '. PRUDHOE BAY DRTLLTNG PBU/S-33 500292229300 NORTH SLOPE COMPUTATTON DATE: 10/14 /92 DATE OF SURVEY' 101492 JOB NUMBER- AK-MW-20080 KELLY BUSHZNG ELEV, = 69,00 FT, OPERATOR' BP EXPLORATZON ZNTERPOLATED VALUES FOR EVEN 10© FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTA MEASD VERTZCAL VERTICAL RECTANGULAR DEPTH DEPTH DEPTH NORTH/SOUTH COORDZNATES EAST/WEST MD-TVD VERTTCAL DTFFERENCE CORRECT]'ON 0 ,00 -69,00 ,00 N ,00 E .00 69 69,00 ,00 ,00 N ,00 E ,00 ,00 169 169,00 100.00 ,16 S ,07 E ,00 ,00 269 269,00 200,00 ,56 S ,25 E ,00 .00 369 369,00 300,00 ,96 S ,43 E ,00 ,00 469 469,00 400.00 1,48 S ,70 E ,00 ,00 569 569.00 500,00 2,23 S 1,15 E ,01 .00 669 669,00 600,00 2,98 S 1,60 E ,01 ,00 769 769,00 700,00 3,74 S 2,03 E ,02 ,00 869 869,00 800,00 5,02 S 2,08 E ,02 ,01 969 969,00 900,00 6,32 S 1069 1069,00 1000,00 7,63 S 1169 1169,00 1100,00 8,94 S 1269 1269,00 1200,00 10,45 S 1369 1369,00 1300,00 12,02 S 2,11 E ,03 ,01 2,13 E ,O4 ,01 2,15 E ,05 ,01 3,71 E ,O8 ,O3 5,80 E ,11 ,03 1469 1469,00 1400,00 13,60 S 1569 1569,00 1500,00 15,18 S 1669 1669,00 1600~00 16,77 S 1769 1769,00 1700,00 18,49 S 1869 1869,00 1800,00 20,21 S 7,89 E ,15 ,03 9,98 E ,18 ,03 12,31 E ,22 .04 16,79 E ,34 ,12 21,27 E .45 .12 1969 1969,00 1900,00 21,93 S 2069 2069,00 2000,00 23,99 S 2169 2169,00 2100,00 27,77 S 2269 2269,00 2200,00 31,55 S 2369 2369.00 2300,00 35,33 S 2469 2469 O0 2400,00 39,13 S 2570 2569,00 2500,00 42,99 S 2670 2669,00 2600,00 46,84 S 2770 2769,00 2700,00 50,89 S 2870 2869,00 2800,00 55,66 S 25,76 E ,57 .12 29,68 E .68 .11 30,76 E ,75 ,08 31,84 E .83 ,08 32,92 E ,91 ,08 33 34 35 35 35 ,89 ,64 ,39 ,89 .38 E ,99 .08 E 1 ,06 .08 E 1, 14 ,08. E 1 , 22 ,08 E 1.34 .11 2970 2969.00 2900,00 60,39 S 3070 3069.00 3000.00 64.68 S 3170 3169.00 3100.00 66.43 S 3270 3269,00 3200.00 64,72 S 3371 3369,00 3300.00 59.84 S 34,53 E 31.38 E 27,53 E 22,71 E 17,02 E 1 ,46 12 1 .60 ,14 1 ,70 ,'10 1 ,83 , 14 2, 12 ,28 S..P__,ERRY-SUN DRZLLTNG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/S-33 500292229300 NORTH SLOPE COHPUTATZON DATE: 10/14/92 DATE OF SURVEY' 101492 JOB NUHBER- AK-HW-20080 KELLY BUSHZNG ELEV, = 69,00 OPERATOR' BP EXPLORATZON FT, ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE HEASD VERTZCAL DEPTH DEPTH SUB-SEA VERTTCAL DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST ND-TVD VERTZCAL DZFFERENCE CORRECTZON 3471 3469,00 3400,00 3571 3569,00 3500,00 3671 3669,00 3600,00 3771 3769,00 3700,00 3871 3869,00 3800.00 53,95 S 12,19 E 49,41 S 9,16 E 46,26 S 7.88 E 43,45 S 7.62 E 40,67 S 7,42 E 2,41 ,29 2.56 , 15 2,62 ,06 2,66 .04 2,70 ,04 3971 3969.00 3900 4071 4069.00 4000 4171 4169.00 4100 4271 4269.00 4200 4372 4369.00 4300 ,00 .00 .00 ,00 .00 37,88 S 7,19 E 2,74 ,04 34,59 S 7,10 E 2,79 .06 31,10 S 7.06 E 2,85 .06 26,47 .S 7,10 E 2,96 .11 21,58 S 7,16 E 3,08 .12 4472 4469,00 4400 4572 4569,00 4500 4672 4669,00 4600 4772 4769,00 4700 4872 4869,00 4800 · 00 16,48 S 5,55 E ,00 I1,37 S 3,76 E ,00 6,18 S 2,24 E ,00 ,92 S ,92 E ,00 4,41 N ,38 W 3,23 ,14 3.37 . 15 3,52 .15 3,67 .15 3,82 ,15 4972 4969,00 4900,00 5073 5069,00 5000,00 5173 5169,00 5100,00 5273 5269,00 5200.00 5373 5369,00'5300,00 9,86 N 1,65 W 15,25 N 3.18 W 20,47 N 5.64 W 25,68 N 8.11 W 30.43 N 11,02 W 3.97 . 16 4.13 .16 4.30 .17 4.46 .17 4.62 ,16 5473 5469,00 5400 5573 5569,00 5500 5674 5669,00 5600 5774 5769.00 5700 5875 5869.00 5800 · 00 34,54 N 14.54 W ,00 39,31 N 18.56 W ,00 45.93 N 24.59 W ,00 52,87 N 32,43 W ,00 59,23 N 41,82 W 4.77 , 15 4,96 ,20 5,38 ,42 5.93 .55 6,58 .65 5976 5969,00 5900 6078 6069.00 6000 6180 6169,00 6100 6284 6269,00 6200 6387 6369,00 6300 ,00 ,00 .00 ,00 ,00 67,12 N 53,65 W 78,04 N 68,98 W 92,29 N 86,05 W 108,91 N 105,33 W 126,22 N 125,54 W 7.60 1.02 9.37 1.77 11.82 2.46 15.01 3.19 18.50 3.49 6491 6469,00 6400 6597 6569,00 6500 6703 6669,00 6600 6812 6769,00 6700 6921 6869,00 6800 ,00 ,00 ,00 ,00 ,00 145.95 N 147.27 W 169.20 N 171.63 W 193,90 N 199.42 W 221.51 N '230,89 W 250.21 N 264.08 W 22.72 4.23 28,24 5,52 34,96 6.72 43.38 8.42 52.59 9,2O SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA ..... , PAGE PRUDHOE BAY DR'i'LLZNG PBU/S-33 500292229300 NORTH SLOPE COMPUTATTON DATE: 10/14/92 DATE OF SURVEY: 101492 JOB NUHBER: AK-HW-20080 KELLY BUSHZNG ELEV. = 69.00 FT. OPERATOR: BP EXPLORATZON ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH 'NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 7031 6969.00 6900.00 281.32 N 297.67 W 62.57 9.98 7141 7069,00 7000.00 312.23 N 331.65 W 72,62 10,05 7251 7169.00 7100,00 343.07 N 365,77 W 82.69 10.07 7361 7269.00 7200,00 372,31 N 399,74 W 92.27 9.59 7470 7369.00 7300.00 400.85 N 433.64 W 101,65 9.38 7580 7469.00 7400,00 429.47 N 467.47 W 111.03 9.38 7689 7569.00 7500.00 458,84 N 500.66 W 120,41 9.38 7798 7669,00 7600,00 487,87 N 534,79 W 130.00 9.58 7909 7769,00 7700,00 515.88 N 571.85 W 140.26 10.27 8020 7869,00 7800.00 543.19 N 610,90 W 151.04 10,78 8131 7969.00 7900.00 571.82 N 649.82 N 162,10 11,06 8241 8069,00 8000.00 598,98 N 688.95 W 172.88 10.78 8352 8169.00 8100.00 623,83 N 728.41 W 183.22 10.34 8462 8269,00 8200.00 647,49 N 768.91 W 193,68 10,46 8573 8369,00 8300.00 670,14 N 809,78 W 204.06 10.38 8592 8386.22 8317.22 673.82 N 816,76 W 205.78 1.72 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT MD (FROM MZNZMUM CURVATURE) POZNTS PERMIT # ~.2.- - COMPLETION DATE .a. OGCC GEOLOGICAL MATERIALS INVENTORY LIST 02.-- WELL NAME ~ ~L,L ~;)"-,.2~ ~ /. ~ /. ~2..,- CO. CONTACT ~ ~.~_ ~ I~¢~t(N~, check off or Ii~t data as it is receiv~d,*list received date for 407'. if not required list as NR ~.z !. ~ l tq I q~' drilling history, v" survey! t ! -." t.~t,o I core descriptio~ cored inte~als core analysis~ d~ ditch intc~als digital data i i LOG TYPE RUN INTERYALS SCALE NO. {to thc nearest foot] , [inchI1 __ z,i P'.Pl~..4oo j "re'~eJ~,g-le. tJ- \ q~:~- q~qq i i i 141 '" ._ II I I I I I I I I I I I I I I I I I BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/28/92 T# 84222 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. R-15~-~[ PRODUCTION LOG 12/17/92 #1 R-31 ~2-~ CL 12/17/92 #1 -33 -10 12/17/92 #1 ~R/~ ~ 12/17/92 #1 8900.00- 9288.00 ATLAS 5 " 9821.00-10441.00 ATLAS 5 " 9000.00- 3394.00 ATLAS 5 " 8820.00- 9394.00 ATLAS 5 " Information Control Well Records RECEIVED JAN 0 4 199,.,z Alaska 011 & Gas Cons. Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 DECEMBER 29, 1992 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 92-0108 PRUDHOE BAY UNIT DS14-43 COMPLETION REPORT 92-0102 PRUDHOE BAY UNIT S-33 COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA AND BP EXPLORATION ALASKA INC. IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. NOVEMBERS MONTHLY PRODUCTION PREPORTS INDICATE THAT THESE WELLS ARE OIL PRODUCER FOR THE YEAR 1992. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE WELLS OR PLUGGING AND ABANDONMENT OF THE ORIGINAL WELL. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MC MAINS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/10/92 T# 84041 PBU/S'33 Tape, OH EDIT Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) ~~5~ ;r'~/ FIN 10/19/92 S-33 OH/BHC$/~ C ~;~N/~ 8044.00- 9529.50 1600BPI API#500292229300 9138->TP# #1 If you have any 564-4004. SCH REF#92 620 Information Control Well RecOrds CEIVED NOV 18 1992 Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/11/92 T# 84043 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-04 ~;-~ PRODUCTION LOG 11/02/92 #1 A- 13~[-I~'~ PRODUCTION LOG 11/05/92 #1 C-19~-$~ PRODUCTION LOG 11/04/92 #1 R-15~3-~; STATIC R-3 I~Z--~ PRODUCTION LOG(~/07 / 92 S-33~-~X ~ ~~( ~-05 8~-g3 P~ODUCTION LOS 10700.00-11130.00 ATLAS 5 " 9200.00- 9700.00 ATLAS 5 " 11100.00-11440.00 ATLAS 5 " 8900.00- 9284.00 ATLAS 5 " 10100.00-10462.00 ATLAS 5 " 9100.00- 9350.00 ATLAS 5 " 530.00-14443.00 ATLAS 2 " 0.00- 9000.00 ATLAS 2 " Information Control Well Records -/ CEIVED NOV 1 8 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/22/92 T# 83986 BP OPEN HOLE LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~fS-33 DIL PHASOR ~S-33 CNL/~ v /S-33 BHC /S~ ~ kS-33 SS TVD ~ 10/19/92 #1 10/19/92 ~1 10/19/92 ~1 10/19/92 #1 9022.00- 9506.00 SCH 8045.00- 9457.00 SCH 9022.00- 9475.00 SCH 9022.00- 9506.00 SCH 2/5" 2/5" 2/5" 1/2" Information Control Well Records RECEIVED OCT 2 9 1992 Alaska Oil & Gas GODS. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION October 2, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Jeff B Hall Workover Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-33 BP Exploration (Alaska), Inc. Permit No: 92-102 Sur. Loc. 1639'SNL, 1487'EWL, Sec. 35, 'T12N, R12E, UM Btmhole Loc. 783'SNL, 5001'WEL, Sec. 35, T12N, R12E, UM Dear Mr. Hall: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~hnston~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '(~'?) prinlgd hr1 recyclr, d p,qp,,r h ,/ ~'? STATE OF ALASKA " ALASKA _ ,L AND GAS CONSERVATION CCI, ,VIISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepeni-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 69feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraoe. Alaska 99519-6612 AI~L 28257 - 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1639' SNL, 1487' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 826' SNL, 4836' WEL, SEC. 35, T12N, R12E S-33 (11-35-12-12) 2S 100302630-277 At total depth 9. Approximate spud date Amount 783' SNL, 5001' WEL, SEC. 35, T12N, R12E 10/3/92 $200,000. O0 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 28258/277'feet S-29 35'@ 900'MD feet 2560 10217'MD/921 l'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (6~, 20 AAC 25.035 (e)(2)) Kickoff depth feet Maximum hole angle 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 We/d 80' 32' 32' 110' 110' 450 # Poleset 13-1/2" 10-3/4" 45.5# NT8OIhe BTC 2928' 31' 31' 2959' 2959' 925 sx AS 111/685 sx AS I 9-7/8" 7-5/8" 29.7# NT95HS NSCC 9662' 30' 30' 9692' 8782' 655 sx Class "G" 6-3/4" 5-1/2" 17# 13CR8O FL4S 675' 9542' 8659' 10217' 9211' 122 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural .~,- Conductor Surface Intermediate Production Liner Alaska Oil & Gas Cons, C0m~issi0~ Perforation depth: measured Anch0rag~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program lXI !Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report• 20 AAC 25.050 requirementsr-I 21.1 hereby~'-~.[]{jclertifY ~tht~, :[, foregoing is true and correct t~[f~ best of my knowledge ,,~.~/.~ Signed ,__/~..L.)-~- Title WorkoverEn~ineerSupervisor Date~.~/, ,.~--.. Commission Use Only Permit Number JAPI number JApproval date See cover letter ~'..~.-,/"~).2_, ~ J50- c>.2.'::2- 2_ ::z_2. ~..? J /~)--::.-,7. -~;-~ for other requirements Conditions of approval Samples required [] Yes J~'No Mud Icg required []Yes.J~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; CI3M; ~5M; I-'I10M; I-]15M; Other: by order of Approved by Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN LOCATION: S-33 Surface: Target' T.D.: [11-35-12-12] PBU 1639' FNL 1487' FWL S35 T12N R12E 826' FNL 4836' FEL S35 T12N R12E 783' FNL 5001' FEL S35 T12N R12E ESTIMATED START: OPR, DAYS TO COMPLETE: ~TOR: OCT 3, 1992 21 (15 days drilling, 6 days completion) Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 35.0/N74.5W/3731'/2.5/3331' Estimated Ground level elevation is 37' AMSL. KB to ground level elevation is 32'. Item TVD(BKB) .MDIBKB) Mud Wt, 20" CONDUCTOR 8 0 8 0 8.5 10-3/4" SHOE 2959 2959 9.1 TOP UGNU SANDS 3 6 6 9 3 6 6 9 9.1 SEABEE 5244 5373 9.5 KUPARUK 6714 71 67 9.8 7-5/8" SHOE 8782 9692 SAG RIVER SANDSTONE 8 7 8 2 9 6 9 2 9.3 - 9.5 TOP SADLEROCHIT 8 90 8 9 8 5 2 9.3 - 9.5 T~ 8908 9852 9.3-9.5 TOTAL DEPTH 9 21 1 1 0 21 7 9.3 - 9.5 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top Btm 30" 20" 91 .5# H-40 WELD 80 32 11 0 1 3-1/2" 1 0-3/4" 45.5# NTSOLHE BTC 2928 3 1 2959 9-7/8" 7-5/8" 29.7# NT95HS NSCC 9662 30 9692 6-3/4" 5-1/2" 1 7# 13Cr-80 FL4S 675 9542 10217 COMPLETION: -- Tubing: 4- 1/2" 1 2.6# 1 3Cr-80 NSCT 9463 2 9 9492 GLMs: 4-1'/2" x 1" - est 6 required, all dummies except RP shear in shallowest GLM Packer: Baker SABL3 7-5/8" x 4-1/2" set at 9492' or +/- 50' above TOL LOC~INGPROGRAM: Open Hole- 9-7/8" Hole' None 6-3/4" Hole: DIL./BHCS/CNL/GR/SP C~, ~-"~?I~ ~ ~''~? ' _O~ No cased hole logs .... 0il & 6a'.; Cor~s. C0ri~r¢.issior~ PROPOSED DRILLING AND COMPLETION PROGRAM WELL S-33 [11-35-12-12] PBI, I MIRU. NU diverter and function test same. Drill 13-1/2" hole to casing point. Run and cement 10-3/4", 45.5#, casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7-5/8", 29.7 # NSCC casing string to within 10' of 9-7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected by dead crude oil. Directionally drill the 6-3/4" hole to TD. Run 5-1/2" liner from TD to 150' inside 7- 5/8" casing shoe and cement using Class G cement. Clean out to 5-1/2" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3500 psi. Run 7-5/8" production packer on tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2300' TVDBKB. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected in a permitted S-pad surface annulus. The completion will include 4-1/2" 13CR NSCT tubing with dummied GLMs, one equalizing dummy, and one RP shear valve ANNULAR INJECTION The S-24 surface annulus is available for injection at present. Fluids can also be injected at the central CC-2 injection facility. AOGCC has informed PB Drilling that only associated fluids from drilling operations can be pumped down the surface x ..~'n~~lr '~ti~_~!~ulus-ie'~ completion fluids cannot be pumped. s-33 Slimhole September27, 1992 14:23 Page 2 S E P 2 8 1992 Alaska 0il & Gas Cons. 6orn,missio~ Anchorage FREEZE PROTECTION The 4-1/2" tubing along with the 4-1/2" annulus will be freeze protected with gas or diesel using the RP shear valve in the shallowest GLM. Dry crude needs to be injected down the 10-3/4" x 7-5/8" annulus after the well is completed. CLOSE APPROACHES/SHUT-INS Note near well proximity of wells S -25 and S 29. The S-25 close approach occurs at 5075' md'. The SSSV will be shut-in and a tail plug installed. The well should be nudged away from S-25 while drilling near 5000' md. The S-25 can be brought back on line once a md of 5575' is reached. The S-29 close approach occurs at 650' md. The SSSV will be shut-in. S-29 can be brought back on line once surface casing td is reached. Notify WOA PE's when wells can be brought back on line. SE P ? 8 1992 ~laska 0il & 6as O01]s. uu[mnissiof~ ~nchorage S-33 Slimhole September27, 1992 14:23 Page 3 500-- 1000~ 1500--- 1944__ 2500-- 2959__ 3000-- 3500-- 3669-- 3732-- 4000-- 4500-- 5000-- 5046 5244 5500-- 6000-- 6500-- 6714 6749 7000-- 7500-- 8000-- 8500-- 8782 8967 9P12 9400 o-- 0,00' @ 0 MD R.K.B. ELEVATION (69.0' JVE SEA LEVEL) VERT I CAL V SCALE 500 O.O0' ~ 1944 MD BASE PERMAFROST 2.50' @ 3832 MD / DIVISIDN Prudhoe Bay Drillin S-Pad Well #33 Nor[h Slope, Alaska I I 500 1000 O, 00'~ 2959 MD 9-5/8' CASING POINT --750 '--500 O. 00'~ 3669 MD UGNU 0.00' @ 3732 MD START OF BUILD ~50 5.00' ~ 3932 MD 7.50 ' ~4032 MD 10.00' ~ 4132 MD 12.50' ~ 4232 MD 15,00' ~ 4332 MD 17.50' e 4432 MD 0 20.00' ~ 4532 MD 22.50' ~ 4632 MD 25, 00' @ 4732 MD 500 27,50' ~ 4832 30.00' e 4932 MD 3~00 Jd~u 3000 2750 2500 ~250 2000 ]750 ]500 ~250 lO00 750 500 250 0 250 32.50' ~ 5032 MD 35. 00' ~ 5]32 MD END OF BUILD .~o~,c.~, H~RIZ~NTAL VIEW (TRUE N~RTH) Anchorage 9HL TVD 9~11,87 ND 10~17, 04 Vg 3331.4 0 No~th 891. 04 ~es~ 3210, 03 VERTICAL 3331 1500 2000 2500 3000 3500 4000 SECTIF1N PLANE: 285,51° File' S33w? 1 VilllLll IiILL;iIIdLII, JIIClI~ IIIL,, Calculated using the Minimum Curvature Method Computed by the SE Win-CADDS System Vertical Section Plane: 285.51 deg. Date: 9/25/~ WetLpath ID: Last Revision: 9)25/S Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.21.12.90 N - Long. 149.01.42.25 g Reference GRID System: Alaska State Pt@ne Zone: ALaska 4 Reference GRID Coordinates (feet): 5979855.00 N 619649.50 E Vertical Section Reference: WELLHEAD North Aligned To: TRUE NORTH Prudhoe Bay Drilling S-Pad gel[ #33 North SLope, ALaska Fite:S33wp1 Measured Inc[ Drift TVD Depth Dir. (ft) (deg) (deg) (ft) R.K.B. ELEVATION (69.0' ABOVE SEA LEVEL) 0.00 0.00 0.00 0.00 BASE PERMAFROST 1944.00 0.00 0.00 1944.00 9-5/8" CASING POINT 2959.00' 0.00 0.00 2959.00 UGNU 3669.00 0.00 0.00 3669.00 START OF BUILD 3731.53 0.00 0.00 3731.53 3831.53 2.50 285.51 3831.50 TOTAL Rectangular Offsets (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 0.00 N 0.00 0.58 N 2.10 3931.53 5.00 285.51 3931.28 2.33 N 8.40 4031.53 7.50 285.51 4030.67 5.24 N 18.89 4131.53 10.00 285.51 4129.50 9.31 N 33.55 4231.53 12.50 285.51 4227.57 4331.53 15.00 285.51 4324.70 4431.53 17.50 285.51 4420.70 4531.53 20.00 285.51 4515.38 4631.53 22.50 285.51 4608.58 4731.53 25.00 285.51 4700.10 4831.53 27.50 285.51 4789.78 4931.53 30.00 285.51 4877.45 5031.53 32.50 285.51 4962.93 14.53 N 52.35 20.89 N 75.25 28.37 N 102.21 36.97 N 133.18 46.66 N 168.10 57.43 N 206.90 69.26 N 249.52 82.13 N 295.86 96.00 N 345.84 Geographic Coordinates Latitude / Longitude 70.21.12.9028 N 149.01.42.2510 70.21.12.9028 N 149.01.42.2510 70.21.12.9028 N 149.01.42.2510 70.21.12.9028 N 149.01.42.2510 70.21.12.9028 N 149.01.42.2510 70.21.12.9085 N 149.01.42.3124 70.21.12.9257 N 149.01.42.4966 70.21.12.9544 N 149.01.42.8032 70.21.12.9944 N 149.01.43.2317 70.21.13.0457 N 149.01.43.7811 70.21.13.1082 N 149.01.44.4505 70.21.13.1818 N 149.01.45.2386 70.21.13.2664 N 149.01.46.1439 70.21.13.3617 N 149.01.47.1646 70.21.13.4677 N 149.01.48.2989 70.21.13.5840 N 149.01.49.5445 70.21.13.7105 N 149.01.50.8991 70.21.13.8470 N 149.01.52.3602 END OF BUILD 5131.53 35.00 285.51 5046.07 110.86 N 399.37 TOP SEABEE (CM3) 5373.16 35.00 285.51 5244.00 147.93 N 532.92 KUPARUK/PUT RIVER 7167.70 35.00 285.51 6714.00 423.23 N 1524.72 429.79 N 1548.33 810.53 N 2919.99 LKRU/LCU 7210.42 35.00 285.51 6749.00 TOP SAG RIVER 9692.26 35.00 285.51 8782.00 70.21.13.9931 N 149.01.53.9248 70.21.14.3577 N 149.01.57.8284 70.21.17.0653 N 149.02.26.8202 70.21.17.1298 N 149.02.27.5105 70.21.20.8745 N 149.03.07.6077 GRID Coordinates Easting Northing (fl) (ft) 619649.50 5979855.00 619649.50 5979855.00 619649.50 5979855.00 619649.50 5979855.00 619649.50 5979855.00 619647.39 5979855.55 619641.06 5979857.20 619630.53 5979859.94 619615.81 5979863.78 619596.93 5979868.69 619573.93 5979874.68 619546.86 5979881.74 619515.76 5979889.84 619480.69 5979898.97 619441.72 5979909.12 619398.92 5979920.27 619352.38 5979932.39 619302.19 5979945.47 619248.43 5979959.47 619114.32 5979994.41 618118.34 5980253.96 618094.62 5980260.14 616717.24 5980619.32 CLosure Dist. Dir. (ft) (deg) 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 2.18 @ 285.51 8.72 @ 285.51 19.61 @ 285.51 34.82 @ 285.51 54.33 @ 285.51 78.09 @ 285.51 106.07 @ 285.51 138.21 @ 285.51 174.46 @ 285.51 214.73 @ 285.51 258.95 @ 285.51 307.05 @ 285.51 358.92 @ 285.51 414.47 @ 285.51 553.07 @ 285.51 1582.37 @ 285.51 1606.88 @ 285.51 3030.40 @ 285.51 Vertical DLS D" -a Section ,,~ (ft) (dg/lOOft) (~) 0.00 0.00 -69,0~ 0.00 0.00 1875.0( 0.00 0.00 2890.0( 0.00 0.00 2.18 8.72 19.61 34.82 54.33 78.09 106.07 138.21 174.46 214.73 258.95 307.05 358.92 414.47 553.07 1582.37 1606.88 3030.40 0.00 3600.01 0.00 3662.5: 2.50 3762.51 2.50 3862.2; 2.50 3961.6 2.50 4060.5i 2.50 4"c8.5 2.50 't'-7' 2.50 ,,,-,., i. 7 2.50 4446.3 2.50 4539.5 2.50 4631.1 2.50 4720.7 2.50 4808.4 2.50 4893.9 2.50 4977.0 0.00 5175.C 0.00 664S.C 0.00 6680.( 0.00 6713.( Date: ~/25/! ~ettpath ID: 5-331J[ Measured Inc[ Drift Depth Dir. (fl) (deg) (deg) TVD (fl) TOP StlUBLIK 9741.09 35.00 285.51 8822.00 TARGET 9918.10 35.00 285.51 8967.00 TOP SAD - Z4B 9968.15 35.00 285,51 9008.00 10018.10 35,00 285.51 9048.92 ZONE 3 10045.06 35.00 285.51 9071.00 ORIGINAl OgC 10067.04 35.00 285.51 9089.00 ZONE 2C 10115.87 35.00 285.51 IOTAL DEPTH 10217.04 35.00 285.51 TOTAL Rectangutar Offsets (fl) (fl) 818.03 N 2946.98 845.18 N 3044.81 852.86 N 3072.47 860.52 N 3100.08 864.66 N 3114.98 868.03 N 3127.12 9129.00 875.52 N 3154.11 9211.87 891.04 N 3210.03 Geographic Coordinates Latitude / Longitude 70.21.20.9482 N 149.03.08.3967 70.21.21.2153 N 149.03.11.2566 70.21.21.2908 N 149.03.12.0653 70.21.21.3661 N 149.03.12.8723 70.21.21.4068 N 149.03.13.3079 70.21.21.4400 N 149.03.13.6629 70.21.21.5137 N 149.03.14.4519 70.21.21.6663 N 149.03.16.0865 GRID Coordinates Easting Northing (fl) (fl) 616690.14 5980626.39 616591.90 5980652.02 616564.12 5980~59.27 616536.40 5980666.50 616521.44 5980670.40 616509.24 5980673.59 616482.14 5980680.66 616426.00 5980695.30 Closure Dist. Dir. (fl) (deg) 3058.41 @ 285.51 3159.94 @ 285.51 3188.65 @ 285.51 3217.30 @ 285.51 3232.76 @ 285.51 3245.36 @ 285.51 3273.37 @ 285.51 3331.40 @ 285.51 Vertical DLS Subsea Section Depth (fl) (dg/lOOft) (fl)' 3058.41 3159.94 3188.65 3217.30 3232.76 3245.36 3273.37 3331.40 0.00 8753.0( O. O0 8898. O( O. O0 8939. O( 0.00 8979.9; 0.00 9002.0( O. O0 o- '-~. O{ .o O. O0 9060. O( 0.00 9142,87 ~,~i i IILI i il IL~'l i IC::lLll~/l i~1~ ii I .......... ~ "'] .......~_ Comlx/ted by the Si/Wir; .... DDS System Calculated using the Minimut,. .urvature Method Normal Plane Method Date: 9/22/92 REFERENCE WELL: Pruclhoe Bay Drilling S-Pad Well #33 North SLope, Alaska Fi[e:S33wp1 TVD, N/S and E/W are measured fro~ the WELLHEAD Wettpath Slot Distance Closest Points sO1 S-01 732.24 sOlr S-O1R 717.97 sO2 S-02 566.20 sO3 S-03 506.13 sO4 S-04 398.23 sO5 S-05 82.45 sO6 S-06 179.45 $07 S-07 69.21 sO8 S-08 32.13 sO9 S-09 141.98 slO S-10 251,88 sll S-ll 328.78 s12 S-12 477.82 s12a S-12A 467.54 s13 S-13 587,44 s14 S-14 697,56 s15 S-15 536,04 s16 S-16 438°02 s17 S-17 952,29 s17a S-17A 952.07 s18 S-18 1027.23 s19 S-19 573.01 s20 S-20 321.15 s21 S-21 474.72 s22 S-22 693.10 s23 S-23 543.16 s24 S-24 367.85 s25 S-25 76.26 s26 S-26 115.76 s27 S-27 254.34 s28 S-28 215.01 s29 S-29 25.20 s30 S-30 98.20 s31 S-31 34.54 s32 S-32 219.39 37p3 S-37 440.54 Direction 270.88 268.14 258.68 270.60 270.45 184.09 232.91 251.82 126.33 121.65 91.35 85.35 90.93 91.04 90.93 90.92 315.83 308.00 234.01 234.01 229.01 237,37 217.02 270.55 270.85 270.71 323.99 179,66 212.24 271.21 270.50 265.04 240.79 269.26 90.61 90.92 Ref MD 50.00 2400.00 3350.00 1350.00 1300.00 4622.26 4051.03 1650.00 3300.00 3350.00 2550.00 2900.00 5O.OO 0.00 150.00 1100.00 4731.42 5075.76 2700,00 2700.00 0.00 4409.86 4786.91 2750.00 950.00 1550.00 4000.62 5075.76 4676.55 1400.00 2250.00 650.00 3300.00 900.00 50.00 50.00 Ref TVD 50.00 2400.00 3350.00 1350.00 1300.00 4600.00 4050.00 1650.00 3300.00 3350.00 2550.00 2900.00 5O,OO 0.00 150.00 1100.00 4700.00 5000.00 2700.00 2700.00 0.00 4400.00 4750.00 2750.00 950.00 1550.00 4000.00 5000.O0 4650.00 1400.00 2250.00 650.00 3300.00 900.00 50.00 50.00 MUD PROGRAM: Well S-33 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE'HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.5 Funnel Viscosity sec/qt ~300 <1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 9- 10 9 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg 9.0-1 0.0 (To to the LCU) 10.0 to Casing Point Yield Point Ibs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel Ibs/100ft2 10 - 20 APl Fluid Loss mi/30 min <15 pH -- 9.5 - 10.0 Hardness mg/i NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAL.;. Watered back mud system used in intermediate hole. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/100ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH -- Hardness m g/I t r 9.5 8- 13 7- 15 ',!~,ncho! a?,¢. 6.0 o 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at < 3500 ,ppm chlorides. S-33 Slimhole September 27, 1992 14:23 Page 4 Over Balance in the Production Hole Design Mud Wt. (6-3/4" Hole): 9.5 ppg. Formation pressure at top Sag River: Formation pressure at Sadlerochit: Pressure at top Sadlerochit: 4200 psi. 3700 psi at 8800' TVDSS 3723 psi. Over Balance Sag River: 215 psi Over Balance Top Sadlerochit: 770 psi. Current GOC: Above top Sad. For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1(file server) under the MUD POLICY folder. H2S: No H2S is anticipated during the drilling of S-33 Oil & (~as Cons. Anchorage S-33Slimhole Septernber 28,1992 9:30 Page 5 CASING SIZE' 10-3/4" 10-3/4" SURFACE CASING CEMENT PROGRAM - DOWELL CIRC. TEMP 38°F SPACER' 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ASIII ADDITIVES: retarder WEIGHT: 12.1 ppg YIELD:1.94 ft3/sx APPROX #SACKS: 925 THICKENING TIME: 4:30 hrs MIX WATER: 11.1 gps TAIL CEMENT TYPE: ASI ADDITIVES: As Required WEIGHT: 15.7 ppg APPROX #SACKS' 435 YIELD:0.93 ft3/sx THICKENING TIME: 4 hrs MIX WATER: 3.59 gps TOP JOB CEMENT TYPE' ASI ADDITIVES: retarder WEIGHT: 15.7 ppg YIELD:0.93 ft3/sx MIX WATER: 3.59 gps APPROX #SACKS: 250 CENTRALIZER .PLACEMENT: 1. Run one(l) boTM type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two cement baskets inside the conductor pipe on stop collars. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 435 sx 3. Top job volume 250 sx. Alaska Oil & Gas (;or~s. Corrtrnis¢Or~ Anchorage S-33 Sliml~ole September27, 1992 14:23 Page 6 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- DOWELL CIRC. TEMP: 140° F SPACER: 50 bbls Mudpush XT, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2% D79 + 0.2% D46 + D800 as required for 4.5 hr thickening time WEIGHT: 11.5ppg YIELD: 2.75ft3/sx MIX WATER: 1 6.9 gps APPROX #SACKS: 392 THICKENING TIME: 4.5 hrs TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.35% D156 + 0.2% D65 + 0.15% D800 + 0.05 gps D47 for 3-4 hrs thickening time. WEIGHT: 15.8ppg YIELD: 1.15ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 263 THICKENING TIME: 3-4 hrs CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator just inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. Batch mix tail cement - perform fluid loss test. Fluid loss should be 40 cc or less. CEMENT VOLUME: 1. Lead G neat slurry to top of Ugnu @ 3669' md. 2. Tail G slurry to 1000' md above casing point with 30% excess. 3. 80' md 7-5/8", 29.7# capacity for float joints. NOTE: The intermediate casing string should be isolated from the Cretaceous interval. S-33 Slimhole September 27, 1992 14:23 .Alask~ 0il & Gas Cons. 6ornmis¢o~ Anchorage Page 7 CIRCo TEMP 140° F 5-1/2" PRODUCTION LINER CEMENT PROGRAM - DOWELL SPACER: 50 bbls fresh water w/3 ppb ARCO preflush and 1% S-400 or equivalent. CEMENT TYPE: CLASS G ADDITIVES: 1.0 gps D600 + 0.25% D65 + 0.1 gps D135 + 0.05 gps D47 + D800 as required WEIGHT: 15.8 ppg YIELD:1.16 ft3/sx MIX WATER' 5.1 gps APPROX #SACKS: 122 THICKENING TIME: 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/ cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 6-8 bpm. LINER CEMENT VOLUME: , Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. Anchorage S-33 Slimhole September27, 1992 14:23 Page 8 S-33 Casing Design Specificatior SURFACE CASING 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 3130 PBYS (#) 1 040000 TJYS (#) 1097000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SlPRESSURE 14 2959 2154 Burst S.F. 2.42 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2959 1462 Collapse S.F. 2.1 4 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 2904 PBYS Tension S.F. 9.21 Mud Wt. 9.5 ppg TJYS 9.71 String Wt. (#) 112946 1~0¢ 0il & Gas Cons. Anchorage S-33 Casing Design Specificatior Intermediate Casing 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 80 71 50 PBYS (#) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SrTP 3330 Burst S.F. 2.46 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 1 0 8800 0.1 3696 Collapse S.Fo 1.93 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9692 PBYS Tension S.F. 3.3 4 Mud Wt. 10.0 TJYS 3.46 String Wt. (#) 242976 AJask~ 0JJ .,Yx Gas Cons, Cornrr~ission Anchorage S-33 Casing Design Specificatior PRODUCTION LINER 5-1/2", 17#,L-80, 13Cr, FL4S Casing GRADE BURST COLLAPSE L-80 6280 7740 PBYS (#) '397000 TJYS (#) 248000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SITP Fluid wt (ppg) 3420 9.6 Burst S.F. 1.74 back up (ppg) Burst Pressure 9.2 3603 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 8800 0.1 3513 Collapse S.F. 2.20 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) I 7 675 9.6 9686 Tension S.F. PBY$ TJYS 40.99 25.60 Armh0~ a~1¢ SUF,.: CL.,OLEDIVERTER SYSTEM-. .... Two lines venting 90 deg. ap~K in directions lhal ensure sm[e down wind venting, and e×- tending to a point at least 100' from any pelential source of ignition. 10' Full Opening Valves .... 35' or as required Dresser Sleeve 1. All pipe connections 150¢- ANSI Flanges or welded connections and secured to prevent movemenL 2_. Manual 10" lull opening valves mechanically c~nnected to ensure that one valve is fail-safe open at all limes. 10' Diverter Uno ,.q. All tums are 90 deg. and targeted. 1 O' Full opening ball valve w/Hyd~ulic Ac--luator Cellar 20' Diverter Spool w/10' Side Outlet MEM 1~0 NABORS 28E 13 5/8" 5,000 psi Stack 2.42 10.93 4 50 4.82 1.51 3.07 2.13 1.13 1.5 GROUND LEVEL ~/ RKB 1 KR TQ BF HYDRIL PIPE RAM BLIND RAM MUD CROSS PIPE RAM I I MUD CROSS TBG SPOOL i FLO( 13.8 5.58 8.O6 ! ~ASE FLG ~~E]// 12.58 I16.25 17.33 19.75 .0it 5: 6a~ Cons. Anchorage DECE,v,, SEP -¢ u 1992 Alaska Ud & Gas Cons. Commission UNP/' t TRIP TANK 170 BBL FILL LINE · VOLUME . TO FLARE U~ Z · CHOKE MANIFOLD ,:...~, ,~...,..:, .~? 1~1 BBL a'~EFLOW DITOH III BBL 'I'AHK DESILTER TO 8TAltO PIPE & KILL L1NE ~UOTIO# 11T BBL MUD PUI~P$ ITO D'STRIDUTIOH MUD IIOPPER8 MIXIIIG 8UGTIOH 1~I4 i]BL BP EXPLORATION BP Exploration(Alaska)lnc. P.O. Box 196612 Anchorage, Naska 99519-6612 ARCO Alaska, Inc. -~~- TO: Name; Company: Location' TELECOPY SATELLITE UNIT FROM: Name & Ext.: Department: NOTES: 'PAGES TO FOLLOW ,. ........ i i' i i iii SECURITY CLASSIFICATION (DO not inclUde cover sheet) PRIVATE SECRET CONFIDENTIAL FAX# -.. SATELLITE FAX MACHINE 907 564-5193 CONFIRM# .,- / ITEM 1) Fee, 2) L,Oc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DaTE [2 thru [8] (3) Adm i nv,<'{'~ E9 tl~r'~J 13] [lO g 13] [14 thru 221 (5) BOPE [ 23 thru . 2 3 4. 5. 6. 7. 8 . 10. 11. 12. 13. 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24 25 26 27. 28. .2_ ~ ~57.' ./ REMARKS Lease & Well ~ NO Company. YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... . Is well located proper distance from other wells ..................... . .... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. ZL Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... . . Is administrative approval needed .................................... Is lease number appropriate .......................................... -~-- ' Does well have a unique name g number ................................ Is conductor string provided ........ ' Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. A//~. .... Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... .~." .. Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old well bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate .... ff~o_~'~ Are necessary diagrams & descriptions of diverter & BOPE attached .... " ~. ~ Does BOPE have sufficient pressure rating -- test to ~-~z:~ psig ..... Does choke manifold comply w/API RP-53 (May 84) .................... ' Is presence of H2S gas probable ...................................... [29 thru 31] (7) Contact ~/~' '[32 ] (8) Addl ~ ~ geo 1 ogy' DWJ~..__ engineer inq' ~G rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEo'L ' UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,= Additional remarks' /- / / / 0 --! -cZ ~..-~ 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. S - 33 PRUDHOE BAY RECEIVED JUL 0 6 199;5 Naska 0il & Gas Cons. Commission Anchorage IC OFILMED Run 1' 28 - March - 1993 PDK-1001GR Borax Log 8969 t265 Tap~ Subtile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD S - 33 (11-35-12-12) 500292229300 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 04-JUN-93 5750.06 K. BRUNNER C. ROBERTSON 35 12N 12E 1639 1487 69.00 68.00 35.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 7.625 9018.0 PRODUCTION STRING 5.500 9510.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GR PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: UNKNOWN EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 8951.0 8972.5 9023.0 9026.0 9044.5 9065.5 9079.5 9088.0 9092.5 9098.5 9109.5 9124.5 9130.0 GRCH 8951.0 8969.0 9019.5 9022.0 9040.0 9062.5 9076.5 9085.0 9088.5 9094.0 9105.5 9119.5 9125.5 29.70 17.00 .9156 ..0 9162.0 9168.5 9176.5 9196.0 9211.5 9232.5 9235.0 9245.0 9251.0 9280.0 $ REMARKS: 9151.0 9157.0 9164.0 9171.5 9191.5 9207.5 9228.5 9231.0 9241.5 9247.5 9280.0 LOG TIED INTO PDK-100/TEMP RUN 17/DEC/92. 3-20-93 TEST DATA: OIL=1.54 MBOPD, WATER=.06 MBWPD, GAS=.9 MMSCFD, LIFT GAS=i.91 MMSCFD, CHOKE=89.8, MANIFOLD TEMP=96 DEGF, MANIFOLD PRESSURE=255 PSI. LOGGED FLOWING PDK PASS, SEAWATER PDK, 20,40,60 & FLUSH PDK PASSES. PUMPED 277 BBL TOTAL FLUID. NOTE: TAPE CORRUPTED DURING LOGGING. RAW FILES ARE OFF DEPTH. DATA OFF DEPTH RELATIVE TO TRUE DEPTH & RELATIVE TO WHAT IS PRESENTED ON BLUELINE. RAW FILES LEFT AS IS. ALL DEPTH CORRECTIONS MADE IN EDITED FILES. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY BP EXPLORATION (ALASKA) INC (21-APR-93). SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8973.0 9255.0 8985.0 9267.0 (MEASURED DEPTH) BASELINE DEPTH SGMA 8951.0 8951.0 8973.0 8969.0 9026.0 9022.0 9045.0 9040.0 9084.0 9081.5 9087.5 9084.0 9094.5 9090.5 9106.5 9101.5 9111.0 9107.5 9124.5 9120.5 9127.0 9123.0 9130.0 9125.5 9156.0 9151.0 9162.0 9157.0 9164.5 9159.5 9169.0 9163.0 9176.5 9171.5 9196.0 9192.0 9211.5 9207.5 9232.5 9228.5 9235.0 9231.0 9245.0 9241.5 9251.0 9247.5 9254.5 9250.5 9280.0 9280.0 EQUIVALENT UNSHIFTED DEPTH REMARKS: FLOWING PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH SHIFTED TO OPEN HOLE GAMMA RAY. $ in separate files. CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 42 Tape File Start Depth = 9280.000000 Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9886 datums Tape Subfile: 2 195 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subf~ile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9004.5 9255.0 9005.0 9266.0 BASELINE DEPTH GRCH 8951.0 8951.0 9004.5 9009.5 9005.0 9022.0 9017.5 9025.5 9021.5 9028.5 9024.0 9030.5 9025.5 9034.5 9029.5 9038.5 9033.0 9044.5 9039.5 9051.0 9045.5 9052.5 9047.5 9054.5 9049.5 9078.0 9075.0 9078.5 9075.0 9080.0 9077.0 9088.0 9084.5 9090.5 9086.5 9098.5 9095.0 9100.0 9095.0 9109.5 9105.0 9111.0 9107.0 9124.5 9119.5 9130.0 9125.5 9138.5 9133.5 9139.5 9134.0 9141.0 9135.5 9141.5 9136.5 9143.0 9138.0 9148.5 9143.0 9155.5 9150.5 9162.0 9156.5 9167.5 9161.5 9168.5 9163.5 9176.5 9171.0 9180.5 9175.0 9182.5 9177.5 in separate files. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8951.0 9000.0 _9186 .~5 9188.5 9196.0 9211.5 9235.5 9245.0 9251.0 9253.0 9253.5 9261.5 9280.0 $ REMARKS: 9182.5 9191.5 9206.5 9230.0 9239.5 9248.5 9280.0 9181.5 9245.5 9247.5 9257.5 9280.0 BASE WATER PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) Total Data Records: 42 966 BYTES * Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 9280.000000 8951.000000 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9886 datums Tape Subfile: 3 120 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8981.0 9256.0 8994.0 9266.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 8951.0 8951.0 8990.5 8985.0 8994.0 9017.5 9023.0 9016.5 9025.5 9019.0 9026.0 9027.5 9028.5 9029.0 9035.5 9044.5 9037.5 9049.0 9049.5 9052.5 9064.5 9060.0 9075.0 9078.0 9073.0 9083.0 9088.0 9081.5 9090.5 9084.0 9097.5 9102.0 9096.0 9106.0 9099.5 9110.0 9103.5 9115.0 9122.0 9124.0 9117.5 9127.5 9130.5 9123.0 9148.0 9149.0 9149.5 9150.0 9154.0 9155.5 9156.0 9149.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 8951.0 8988.0 9011.5 9017.0 9019.5 9021.0 9021.5 9022.0 9028.0 9041.5 9042.5 9045.5 9070.0 9078.0 9090.5 9095.0 9108.5 9115.5 9120.5 9141.0 9141.5 9142.0 9143.0 9147.0 9148.0 ~9157 .- 0 9161.5 9167.0 9168.5 9176.0 9188.0 9196.5 9232.5 9235.5 9245.0 9252.0 9254.0 9256.0 9258.5 9265.0 9280.0 $ REMARKS: 9155.0 9160.0 9162.0 9169.0 9181.0 9189.5 9225.5 9228.5 9238.0 9246.5 9280.0 9149.5 9238.0 9244.5 9248.5 9253.5 9260.0 9280.0 20 BBL BORAX AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 42 Tape File Start Depth = 9280.000000 Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19772 datums Tape Subfile: 4 125 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8981.0 PDK 8995.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 8951.0 8951.0 8986.5 8981.0 8995.0 9002.0 9016.5 9022.5 9025.5 9019.5 9027.0 9027.5 9028.0 9029.0 9030.5 9035.0 9035.5 9036.5 9042.0 9044.0 9038.0 9048.0 9049.0 9049.5 9051.5 9052.5 9075.0 for each pass in separate files. STOP DEPTH 9256.0 9266.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8951.0 8988.5 8995.5 9010.5 9016.5 9020.5 9023.0 9023.5 9024.0 9025.5 9028.0 9028.5 9029.0 9034.5 9041.0 9042.0 9043.0 9045.0 9045.5 9070.0 9078.5 9073.0 9083.5 9078.5 9090.5 9084.5 9094.5 9087.5 9098.0 9091.0 9101.5 9094.5 9102.0 9096.0 9106.0 9100.0 9110.0 9103.0 9104.0 9111.5 9105.0 9122.0 9116.0 9127.0 9120.5 9130.5 9123.5 9132.0 9125.5 -9133 ,.0 9133.5 9134.0 9135,0 9156.0 9161,5 9167,0 9168,5 9176,0 9188,0 9196,0 9205,0 9212,0 9232.5 9235,0 9245.0 9254,0 9256,0 9258,5 9265,0 9280,0 $ REMARKS: 9149,5 9155,0 9160,5 9161,5 9168,5 9181,5 9189,5 9198,5 9205,0 9225,5 9228,5 9238,0 9246.5 9280.0 9126,0 9127,0 9127.5 9128,0 9249,0 9253,5 9260,0 9280.0 40 BBL BORAX AWAY, ALL PDK CURVES WERE SHIFTED WITH SGMA, $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code 1 GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 S~ PDK 68 8 MSD PDK 68 9 RATO PDK 68 10 RBOR PDK 68 11 RICS PDK 68 12 RIN PDK 68 13 SGMA PDK 68 14 SGMB PDK 68 Samples Units Size 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 CU 4 1 CPS 4 1 CPS 4 1 CU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 * DATA RECORD (TYPE# 0) Total Data Records: 42 966 BYTES * 56 Tape File Start Depth = 9280.000000 Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19772 datums Tape Subfile: 5 130 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8980.0 9256.0 8995.0 9266.0 BASELINE DEPTH GRCH 8951.0 8951.0 8995.0 8998.0 8992.5 9016.0 9009.0 9022.5 9015.5 9023.5 9016.0 9025.5 9019.0 9027.5 9020.0 9028.5 9020.5 9033.0 9025.0 9035.0 9027.5 9038.0 9030.5 9039.0 9031.0 9044.5 9036.5 9047.5 9039.5 9048.0 9040.5 9050.0 9042.5 9050.5 9043.5 9053.0 9046.0 9075.0 9069.5 9079.0 9073.5 9083.5 9078.0 9087.5 9082.0 9094.5 9086.5 9097.5 9090.0 9098.5 9091.0 9099.5 9091.5 9101.5 9093.5 9102.5 9095.5 9104.0 9096.5 9109.5 9102.5 9111.5 9105.0 9112.5 9106.5 9113.5 9107.0 9122.0 9115.0 9124.5 9116.5 9130.0 9124.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8951.0 8988.0 9132.0 9133.0 9133.5 9134.5 9135.5 9156.0 9157.0 9162.0 9167.0 9169.0 9176.0 9188.0 9196.0 9205.5 9211.5 9232.5 9235.5 9245.0 9253.5 9254.5 9255.5 9258.5 9265.0 9280.0 $ REMARKS: 9125.0 9125.5 9126.5 9127.5 9128.0 9148.5 9149.5 9154.0 9159.5 9161.5 9168.5 9180.5 9189.0 9197.5 9204.0 9224.0 9227.0 9236.5 9245.5 9246.0 9247.5 9252.5 9259.0 9280.0 9280.0 60 BBL BORAX AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GRCH PDK 2 BIF PDK 3 BKL PDK 4 BKS PDK 5 CSLS PDK 6 LS PDK 7 SS PDK 8 MSD PDK 9 RATO PDK 10 RBOR PDK 11 RICS PDK 12 RIN PDK 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 GAPI CPS CPS CU CPS CPS CU 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 .13 .SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU * DATA RECORD (TYPE# 0) Total Data Records: 42 966 BYTES * 4 96 761 61 4 00 201 24 56 Tape File Start Depth = 9280.000000 Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29658 datums Tape Subfile: 6 133 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8981.0 9258.0 8995.0 9268.0 BASELINE DEPTH GRCH 8951.0 8951.0 8998.0 8990.5 9001.0 9022.5 9023.5 9026.0 9018.0 9030.5 9031.5 9044.5 9035.5 9052.0 9063.0 9063.5 9065.5 9066.5 9067.0 9075.0 9075.5 9076.0 9077.0 9079.0 9072.5 9087.5 9080.5 9090.0 9083.5 9094.5 9086.0 9097.5 9099.0 9100.0 9101.5 9102.5 9094.5 9104.0 9096.0 9102.5 9106.0 9116.0 9122.0 9109.5 9113.5 9114.5 9122.0 9124.5 9126.0 9130.5 9135.0 (MEASURED DEPTH) in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 8951.0 8993.5 9015.0 9015.5 9022.5 9023.0 9043.5 9056.0 9057.0 9059.0 9059.5 9060.0 9068.5 9069.0 9070.0 9071.0 9089.5 9091.0 9091.5 9093.0 9107.0 9114.5 9118.0 9127.0 9136.Q 9154.5 9155.5 9162.0 9167.0 9169.0 9176.5 9188.0 9196.0 9196.5 9232.5 9235.5 9244.5 9253.5 9254.5 9257.0 9265.5 9280.0 $ REMARKS: 9148.0 9153.5 9158.5 9160.5 9167.5 9180.0 9187.5 9223.0 9226.5 9235.5 9244.5 9280.0 9127.5 9146.0 9188.0 9244.5 9248.5 9257.0 9280.0 FLUSH PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 O0 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 42 Tape File Start Depth = 9280.000000 Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29658 datums Tape Subfile: 7 127 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8968.0 PDK 8980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9255.0 9268.0 28-MAR-93 FSYS REV. J001 VER. 1.1 1252 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9510.0 0.0 PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE cOUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS) : 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN) : 0.0 REMARKS: FLOWING PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SS PDK 68 1 CPS 4 20 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 107 Tape File Start Depth = 9271.000000 .Tape File End Depth = 8951.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56560 datums Tape Subfile: 8 182 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 9 is type: LIS 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: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8999.5 PDK 8999.5 $ 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 9255.0 9268.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAR-93 FSYS REV. J001 VER. 1.1 1429 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9510.0 0.0 PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 800 FAR COUNT RATE HIGH SCALE (CPS) : 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASE WATER PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SS PDK 68 1 CPS 4 20 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 80 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 91 Tape File Start Depth = 9271.000000 · Tape'File End Depth = 8999.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52528 datums Tape Subfile: 9 166 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8976.0 PDK 8987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9254.0 9266.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAR-93 FSYS REV. J001 VER. 1.1 1508 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9510.0 0.0 PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 20 BBL BORAX PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SS PDK 68 1 CPS 4 20 SPD PDK 68 1 F/MN 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 00 201 24 4 71 162 89 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 05 626 89 4 05 626 89 0 1 6 6 6 1 1 1 1 1 6 1 0 0 0 0 6 1 6 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 102 Tape File Start Depth = 9270.000000 ,Tape. File End Depth = 8965.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82202 datums Tape Subfile: 10 177 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8975.0 PDK 8987.0 $ LOG HEADER DATA STOP DEPTH 9255.0 9268.0 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 PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-MAR-93 FSYS REV. J001 VER. 1.1 1530 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9510.0 0.0 PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 40 BBL BORAX PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SS PDK 68 1 CPS 4 20 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 103 Tape File Start Depth = 9271.000000 'Tape'File End Depth = 8965.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 78254 datums Tape Subfile: 11 178 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8975.0 PDK 8987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9255.0 9268.0 28-MAR-93 FSYS REV. J001 VER. 1.1 1550 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK- 100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XB 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9510.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0. 000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 ~ASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN) : 0.0 REMARKS: 60 BBL BORAX PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CCL PDK 68 6 CSLS PDK 68 7 CSS PDK 68 8 G1 PDK 68 9 G2 PDK 68 10 ISS PDK 68 11 LS PDK 68 12 MSD PDK 68 13 RATO PDK 68 14 RBOR PDK 68 15 RICS PDK 68 16 RIN PDK 68 17 SGMA PDK 68 18 SGMB PDK 68 19 SS PDK 68 20 SPD PDK 68 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 4 1 CU 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 1 CPS 4 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 103 Tape File Start Depth = 9271.000000 'Tape"File End Depth = 8965.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 107928 datums Tape Subfile: 12 178 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8974.0 PDK 8986.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9255.0 9268.0 28-MAR-93 FSYS REV. J001 VER. 1.1 1630 28-MAR-93 9430.0 9270.0 9000.0 9270.0 1500.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9510.0 0.0 PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 'BASE NORMALIZING WINDOW (FT): 0.0 FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER 800 3300 0 60000 TOOL STANDOFF (IN) : REMARKS: FLUSH PASS. $ CN : BP EXPLORATION WN : S - 33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SS PDK 68 1 CPS 4 20 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 103 Tape File Start Depth = 9271.000000 'Tape' File End Depth = 8964.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 104064 datums Tape Subfile: 13 178 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 14 is type: LIS 93/06/04 01 **** REEL TRAILER **** 93/ 6/ 5 01 Tape Subfile: 14 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 5 JUN 93 9:54a Elapsed execution time = 1 minute , 8.2 seconds. SYSTEM RETURN CODE = 0 RECEIVED MAR 1 0 1995 Alaska 0ii & Gas Cons. Commission S- 33 PRUDHOE BAY MICI OFILM I II Run 1' 17 - December - 1992 PDK-100/GR 8979 Tape Subfile 2. is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD S-33 (11-35-12-12) 500292229300 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 20 - FEB- 93 5750.01 K. BRUNNER L. LE 35 12N 12E 1639 1487 RECEIVED MAR i 0 i99,3 Alaska Oil & Gas Cons. Commission Anchorage 69.00 68.00 35.60 OPEN HOLE CASING DRILLERS CASING 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA'- ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.625 9018.0 29.70 5.500 9510.0 17.00 4.500 8824.0 12.60 UNKNOWN BASELINE DEPTH 9028.5 9034.0 9039.5 9044.0 9048.5 9052~5 9053.0 9055.5 9057.5 9050.0 9078.0 9078.5 9079.5 GRCH 9029.0 9034.5 9039.5 9044.0 9049.0 9053.0 9054.0 9056.5 9059.5 9060.0 9079.5 9080.0 9080.5 EQUIVALENT UNSHIFTED DEPTH GR 9130.0 9131.0 9144.0 9147.0 9155.0 9155.5 9169.5 9178.5 9191.5 9192.5 9306.0 9307.0 9309.0 9310.5 9311.0 $ REMARKS: 9131.0 9131.5 9144.5 9147.0 9155.0 9156.0 9170.0 9178.5 9191.5 9193.0 9306.5 9307.0 9309.5 9311.0 9311.5 LOG TIED INTO SONIC RUN 19-OCT-92. WELL TEST PRIOR TO LOGGING: OIL = .6 MBOPD WATER = 3.44 MBWPD GAS = .93 MMSCFPD LIFT GAS = .61 MMSCFPD CHOKE = 95.5 WHFTP = 278 PSI WHFTT = 166 F PDK PASSES: 1. WELL FLOWING 2. BASE SEAWATER PASS 3. 20 BBLS BORAX AWAY 4. 40 BBLS BORAX AWAY 5. 60 BBLS BORAX AWAY 6. 20 BBLS SEAWATER FLUSH PUMPED 398 BBLS FLUID TOTAL. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY BP EXPLORATION (12-FEB-93) . SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 8963.0 8963.0 8995.5 8995.5 9020.0 9020.5 9023.0 9022.5 9042.5 9042.0 9045.0 9044.5 9049.0 9047.0 9085.0 9086.0 9107.0 9107.5 9113.0 9114.0 9118.0 9118.5 9122.0 9123.5 9124.0 9125.0 9129.5 9131.0 9156.0 9156.0 9164.0 9164.0 9169.0 9168.5 9176.0 9176.0 9196.0 9197.0 9212.0 9212.5 9232.5 9233.0 9245.0 9245.5 9254.0 9254.0 9301.0 9301.5 9315.0 9315.5 9345.0 9346.0 9361.5 9361.5 9408.0 9408.0 CN WN FN COUN START DEPTH STOP DEPTH 8979.5 9370.5 8993.5 9382.5 (MEASURED DEPTH) REMARKS: EQUIVALENT UNSHIFTED DEPTH PDK/GR - WELL FLOWING PASS. GRCH WAS MATCHED TO OH GR. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : BP EXPLORATION : S-33 : PRUDHOE BAY : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 00 201 24 4 71 162 89 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 05 626 89 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 56 Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13366 datums Tape Subfile: 2 221 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS 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 PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8980.5 9381.5 8993.5 9393.5 (MEASURED DEPTH) BASELINE DEPTH GRCH 8974.0 8975.0 8983.5 8984.5 8988.0 8988.0 9000.5 9000.5 9001.5 9001.0 9002.0 9002.0 9006.0 9006.0 9007.0 9006.5 9028.0 9028.5 9032.0 9032.5 9033.0 9033.0 9033.5 9034.0 9034.5 9034.0 9035.5 9036.0 9034.5 9036.5 9036.5 9046.0 9046.0 9045.0 9046.5 9047.0 9049.5 9048.0 9051.0 9049.5 9052.0 9050.0 9053.0 9051.0 9054.0 9051.5 9054.5 9052.0 9055.0 9053.0 9055.5 9056.0 9056.0 9057.0 9054.0 9056.5 9057.5 9055.0 9057.0 9055.5 9058.0 9056.0 9066.0 9065.0 9066.5 9065.5 9067.5 9066.0 9068.5 9067.0 9076.5 9076.5 9077.0 9077.0 9078.0 9079.5 9079.0 9080.5 EQUIVALENT UNSHIFTED DEPTH SGMA 9079.5 9080.0 9096.0 9098.5 9099.5 9100.0 9100.5 9101.5 9106.5 9107.0 9107.5 9109.5 9110.0 9112.5 9129.5 9130.0 9131.5 9132.5 9135.0 9136.0 9143.5 9144.0 9144.5 9146.0 9155.0 9156.0 9156.5 9174.0 9175.5 9180.5 9181.0 9189.5 9190.0 9190.5 9191.0 9192.0 9204.0 9206.5 9216.0 9216.5 9217.0 9217.5 9222.0 9223.0 9223.5 9224.0 9226.0 9227.0 9227.5 9239.5 9240.5 9241.0 9242.0 9243.0 9244.5 9245.5 9248.0 9255.0 9257.5 9258.5 9081.0 9097.0 9101.5 9102.0 9102.5 9107.5 9108.5 9109.0 9113.5 9136.0 9136.5 9144.5 9146.0 9156.0 9157.0 9174.5 9175.5 9181.0 9191.5 9192.0 9192.5 9242.5 9243.0 9248.0 9255.5 9259.0 9080.5 9099.5 9100.0 9110.0 9111.0 9130.5 9131.5 9133.0 9133.5 9144.5 9145.0 9155.5 9156.0 9180.5 9181.5 9190.0 9191.0 9205.0 9207.0 9216.5 9217.0 9217.5 9218.5 9223.0 9223.5 9224.0 9225.0 9227.0 9227.5 9228.5 9240.5 9241.0 9242.0 9245.5 9246.0 9258.0 9258.5 9260.5 9261.0 9266.0 9266.5 9267.5 9268.0 9269.0 9269.5 9274.0 9290.0 9295.0 9295.5 9304.5 9305.0 9306.5 9310.0 9324.5 9327.5 9329.0 9330.0 9343.5 9344.0 9352.0 9353.0 9353.5 9354.5 9367.0 9374.0 9376.0 9383.0 9384.0 9385.0 9385.5 9393.0 9393.5 9394.0 9398.0 9398.5 $ REMARKS: 9260.5 9261.5 9267.0 9267.5 9268.0 9268.5 9268.5 9269.0 9269.5 9274.5 9290.0 9295.0 9296.0 9305.0 9306.0 9307.5 9310.5 9325.0 9329.0 9330.5 9331.0 9344.5 9345.5 9353.5 9354.0 9354.5 9355.0 9367.5 9374.0 9376.0 9382.5 9386.5 9384.5 9385.0 9395.5 9396.0 9396.5 9400.5 9401.0 PDK/GR - BASE SEAWATER PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 56 * DATA RECORD (TYPE# 0) Total Data Records: 56 966 BYTES * Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13366 datums Tape Subfile: 3 221 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS 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 PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8982.5 9381.5 8995.5 9393.5 BASELINE DEPTH GRCH 8974.0 8977.0 8983.5 8986.5 8988.0 8997.5 9000.0 9001.5 9003.0 9005.0 9005.5 9007.5 9019.0 9020.5 9021.5 9022.0 9027.5 9028.5 9028.0 9028.5 9033.0 9034.0 9034.0 9034.5 9035.5 9036.5 9037.0 9037.5 9037.5 9046.0 9046.0 9046.5 9047.0 9051.0 9051.5 9052.5 9053.0 9054.0 9054.5 9055.0 9055.5 9056.0 9056.0 9056.5 9057.0 9057.0 9057.5 9058.0 9057.5 9059.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8990.0 8999.5 9000.0 9001.0 9002.0 9004.0 9005.5 9007.5 9018.0 9019.5 9020.0 9021.0 9027.0 9028.0 9035.0 9035.5 9045.0 9049.5 9050.0 9050.5 9051.0 9051.5 9053.0 9055.0 9055.5 9057.0 9060.5 9061.0 9062.0 9066.0 9069.5 9070.0 9078.0 9078.5 9079.0 9080.0 9080.5 9081.0 9092.0 9093.0 9095.5 9100.0 9100.5 9101.5 9108.5 9110.0 9124.5 9126.5 9128.5 9129.5 9130.5 9131.0 9131.5 9132.5 9133.5 9137.5 9138.5 9140.5 9141.0 9144.5 9145.0 9145.5 9146.0 9153.0 9154.0 9157.0 9157.5 9168.5 9169.5 9173.0 9173.5 9175.0 9176.5 9177.0 9177.5 9178.5 9181.0 9182.0 9190.5 9191.5 9192.5 9210.5 9223.0 9240.5 9241.0 9242.0 9060.0 9061.0 9062.0 9080.0 9080.5 9081.0 9096.5 9101.5 9102.0 9102.5 9129.5 9130.0 9131.0 9132.0 9132.5 9133.0 9145.5 9146.0 9157.0 9158.0 9174.0 9176.5 9181.0 9191.5 9192.5 9193.0 9211.0 9241.5 9242.0 9242.5 9065.5 9069.0 9070.0 9079.5 9080.0 9080.5 9081.0 9082.0 9093.0 9093.5 9109.0 9111.0 9125.5 9128.0 9134.0 9134.5 9138.5 9139.0 9141.0 9142.0 9145.5 9146.0 9153.5 9154.0 9168.5 9169.0 9172.5 9175.0 9176.5 9177.5 9178.0 9178.5 9181.0 9182.5 9223.5 9246.5 9247.5 9252.5 9260.5 9263.0 9263.5 9264.5 9266.0 9267.0 9269.0 9289.0 9294.0 9294.5 9295.0 9305.0 9305.5 9306.5 9309.0 9310.5 9311.0 9312.0 9323.5 9324.0 9327.5 9328.0 9329.0 9329.5 9330.5 9337.0 9338.0 9338.5 9340.0 9349.5 9355.5 9356.0 9356.5 9357.5 9364.5 9365.5 9374.0 9375.0 9376.0 9376.5 9383.0 9398.0 9398.5 $ REMARKS: 9247.0 9247.5 9253.0 9261.0 9263.0 9263.5 9264.0 9265.5 9266.0 9268.0 9289.5 9294.5 9295.0 9295.5 9305.5 9306.5 9307.5 9309.5 9312.5 9323.5 9324.0 9341.0 9350.5 9357.0 9357.5 9358.0 9365.0 9386.5 9401.5 9402.0 9313.0 9313.5 9329.0 9329.5 9330.0 9330.5 9331.0 9337.5 9338.0 9338.5 9354.0 9354.5 9355.0 9363.0 9374.0 9375.0 9375.5 9376.0 PDK/GR - 20 BBLS BORAX AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH-PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 56 Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26732 datums Tape Subfile: 4 229 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8982.5 9381.5 8995.5 9393.5 BASELINE DEPTH GRCH 8974.0 8977.0 8983.5 8986.5 8988.0 8997.5 8999.5 9001.0 9026.5 9027.0 9027.5 9027.5 9028.0 9030.5 9031.5 9032.0 9033.0 9033.5 9035.0 9037.0 9037.5 9042.5 9043.5 9046.0 9048.0 9048.5 9050.0 9052.5 9053.5 9054.0 9054.5 9057.0 9057.5 9058.0 9060.0 9066.0 9069.0 9079.0 9079.5 9080.5 9032.5 9033.0 9034.0 9035.5 9036.0 9037.5 9048.0 9049.0 9057.5 9058.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8990.0 8999.5 9000.0 9000.5 9026.0 9026.5 9027.5 9030.0 9030.5 9041.5 9042.0 9044.5 9048.0 9050.5 9051.0 9051.5 9052.5 9055.0 9055.5 9057.5 9065.0 9068.0 9080.0 9080.5 9081.0 9081.0 9089.0 9089.5 9090.0 9090.5 9096.0 9098.5 9107.0 9108.0 9112.0 9112.5 9113.0 9114.0 9114.5 9115.0 9115.5 9123.5 9125.0 9126.0 9136.5 9137.5 9143.5 9144.5 9145.5 9146.5 9147.5 9148.0 9148.5 9150.5 9151.5 9153.5 9154.0 9161.5 9162.5 9170.5 9171.5 9172.0 9179.5 9180.5 9181.0 9182.0 9190.5 9213.5 9214.5 9215.5 9240.5 9241.5 9258.5 9259.0 9263.5 9266.0 9266.5 9267.5 9268.0 9288.5 9294.0 9294.5 9295.0 9321.5 9323.5 9090.0 9090.5 9096.5 9099.5 9108.0 9108.5 9115.0 9124.5 9126.0 9126.5 9144.0 9144.5 9145.5 9146.0 9153.0 9154.0 9181.0 9191.0 9214.0 9214.5 9216.0 9241.0 9241.5 9258.5 9259.5 9263.0 9266.0 9266.5 9267.0 9267.5 9288.5 9294.0 9294.5 9295.0 9321.5 9324.0 9082.0 9090.5 9091.0 9112.5 9113.5 9114.0 9114.5 9115.5 9116.5 9137.5 9138.0 9147.0 9147.5 9148.0 9149.0 9151.0 9151.5 9161.5 9162.0 9170.0 9170.5 9171.5 9179.5 9180.5 9182.5 9324.5 9325.5 9326.5 9329.0 9331.0 9338.0 9340.0 9344.0 9348.5 9356.0 9356.5 9357.5 9363.0 9365.0 9374.0 9374.5 9375.5 9376.0 9376.5 9384.5 9398.0 9398.5 $ REMARKS: 9325.0 9325.5 9327.0 9329.5 9331.5 9330.5 9337.5 9338.0 9342.0 9348.5 9353.5 9354.0 9354.5 9363.0 9362.0 9373.5 9374.0 9374.5 9375.0 9375.5 9386.5 9400.0 9400.5 PDK/GR - 40 BBLS BORAX AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 05 626 89 6 * DATA RECORD (TYPE# 0) Total Data Records: 56 966 BYTES * 56 Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26732 datums Tape Subfile: 5 205 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8980.5 9381.5 8993.5 9394.5 BASELINE DEPTH GRCH 8974.0 8975.0 8983.5 8984.5 8988.0 8994.5 8994.5 8999.5 8999.5 9001.5 9003.5 9004.5 9005.0 9005.5 9006.5 9014.5 9015.0 9016.0 9016.5 9017.0 9017.0 9018.0 9018.0 9018.5 9019.0 9019.0 9020.0 9020.5 9028.0 9028.0 9028.5 9029.0 9035.0 9035.5 9035.5 9036.0 9036.0 9037.0 9037.5 9038.0 9046.5 9048.0 9048.0 9048.5 9049.0 9049.5 9052.0 9053.0 9053.5 9054.0 9054.0 9054.5 9054.5 9056.0 9056.0 9056.5 in separate files. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8988.0 9001.5 9003.0 9003.5 9004.0 9005.0 9006.0 9016.0 9018.5 9019.0 9027.0 9028.0 9035.0 9035.5 9036.0 9037.0 9045.5 9048.0 9050.5 9051.0 9052.0 9053.0 9055.0 9057.5 9060.5 9061.0 9062.0 9069.0 9070.0 9077.0 9077.5 9078.5 9079.0 9080.0 9108.5 9110.5 9116.0 9124.5 9128.0 9128.5 9129.0 9130.0 9133.5 9134.5 9135.0 9135.5 9136.5 9137.5 9141.0 9142.0 9149.5 9150.5 9162.0 9166.0 9170.0 9170.5 9171.0 9172.0 9173.0 9180.5 9182.0 9184.0 9190.0 9190.5 9191.5 9216.5 9223.0 9224.0 9235.0 9235.5 9240.5 9241.0 9242.0 9267.0 9268.0 9269.0 9286.0 9288.5 9289.0 9299.0 9300.0 9300.5 9301.0 9062.5 9063.0 9063.5 9080.5 9081.0 9117.0 9125.0 9128.5 9129.5 9130.0 9130.5 9141.5 9142.0 9170.0 9171.0 9171.5 9172.0 9180.5 9191.0 9191.5 9192.0 9217.0 9238.0 9238.5 9241.0 9241.5 9242.0 9267.0 9267.5 9268.5 9288.5 9300.0 9300.5 9301.0 9055.5 9067.0 9067.5 9077.0 9078.0 9079.5 9080.0 9080.5 9109.0 9111.5 9134.5 9135.0 9135.5 9136.5 9137.5 9138.0 9150.0 9150.5 9162.0 9165.5 9172.5 9182.5 9184.5 9222.5 9223.5 9286.0 9289.0 9298.5 9300.5 9304.5 9305.0 9308.5 9309.5 9312.0 9317.0 9322.0 9324.5 9327.5 9328.5 9329.5 9330.5 9331.0 9331.5 9332.0 9337.0 9338.0 9348.0 9364.0 9364.5 9375.5 9376.5 $ REMARKS: 9304.5 9305.5 9309.0 9309.5 9312.0 9316.5 9321.5 9323.5 9331.0 9348.5 9364.5 9365.0 9328.0 9329.0 9329.5 9330.0 9330.5 9331.5 9337.0 9337.5 9375.0 9376.0 PDK/GR - 60 BBLS BORAX AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SS PDK 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 * DATA RECORD (TYPE# 0) Total Data Records: 56 966 BYTES * 56 Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40098 datums Tape Subfile: 6 205 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8982.5 9381.5 8995.5 9393.5 BASELINE DEPTH GRCH 8974.0 8977.0 8983.5 8986.5 8988.0 8997.5 8999.5 9001.0 9003.5 9004.0 9007.0 9019.0 9020.0 9020.5 9020.5 9021.0 9028.0 9028.0 9030.0 9030.0 9031.0 9030.5 9032.0 9031.5 9032.5 9032.5 9035.0 9035.0 9036.0 9035.5 9037.0 9037.5 9038.0 9040.5 9041.5 9042.5 9042.0 9043.0 9043.0 9046.0 9048.5 9048.5 9049.0 9049.5 9049.5 9052.5 9053.0 9053.5 9053.5 9054.0 9054.0 9054.5 9057.5 9058.0 9058.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8990.0 8999.5 9000.0 9000.5 9003.0 9005.0 9008.0 9018.0 9035.0 9035.5 9036.0 9037.0 9039.5 9040.0 9044.5 9047.5 9050.5 9051.0 9051.5 9052.5 9055.5 9060.0 9063.5 9065.5 9068.5 9069.5 9077.5 9078.5 9096.0 9098.0 9099.0 9100.0 9106.5 9107.0 9107.5 9117.5 9121.5 9132.5 9133.5 9135.0 9136.0 9138.0 9139.0 9139.5 9145.0 9145.5 9146.0 9146.5 9156.5 9157.0 9157.5 9158.5 9159.0 9159.5 9160.5 9170.5 9171.5 9172.0 9172.5 9173.5 9174.0 9175.0 9176.0 9177.5 9178.0 9180.0 9181.0 9182.0 9190.5 9199.5 9200.5 9201.0 9201.5 9207.5 9221.0 9222.0 9236.5 9237.0 9239.0 9240.0 9240.5 9060.5 9064.5 9069.5 9078.0 9096.5 9101.0 9107.5 9108.0 9135.5 9136.0 9145.5 9146.0 9156.0 9157.0 9174.0 9175.5 9177.0 9178.0 9180.0 9180.5 9191.0 9200.0 9200.5 9201.0 9202.0 9207.5 9237.0 9240.5 9241.0 9064.5 9068.5 9079.0 9098.5 9099.0 9106.5 9107.5 9118.0 9122.5 9133.5 9134.0 9138.5 9139.0 9140.0 9145.5 9146.0 9157.5 9158.0 9159.0 9159.5 9160.0 9170.0 9170.5 9171.5 9172.0 9172.5 9174.5 9180.5 9182.5 9221.5 9222.0 9236.5 9237.5 9239.5 9241.5 9246.5 9247.5 9248.0 9248.5 9253.0 9257.5 9258.0 9258.5 9259.0 9259.5 9260.0 9264.0 9264.5 9265.0 9266.0 9267.0 9267.5 9268.5 9277.5 9289.0 9294.0 9295.0 9296.5 9297.0 9312.0 9314.0 9318.0 9319.0 9327.5 9330.0 9331.0 9338.0 9338.5 9339.0 9340.0 9343.5 9349.5 9350.0 9356.0 9357.0 9362.5 9363.0 9364.5 9365.5 9374.5 9375.5 9376.5 9384.5 9385.0 $ REMARKS: CN WN FN COUN 9241.5 9246.5 9247.0 9247.5 9253.0 9258.0 9259.0 9260.0 9263.0 9263.5 9264.5 9265.0 9266.0 9267.5 9289.0 9294.0 9294.5 9296.0 9297.0 9312.0 9317.5 9318.5 9338.0 9349.5 9350.5 9356.5 9357.0 9362.5 9363.0 9248.0 9257.0 9257.5 9258.0 9258.5 9259.0 9263.5 9277.5 9314.0 9328.0 9330.5 9331.0 9338.5 9339.5 9340.5 9343.5 9364.5 9365.0 9374.0 9374.5 9375.0 9383.0 9383.5 PDK/GR - 20 BBLS SEAWATER FLUSH. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : BP EXPLORATION : S-33 : PRUDHOE BAY : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 05 626 89 6 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 56 Tape File Start Depth = 9408.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40098 datums Tape Subfile: 7 233 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8979.0 PDK 8990.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9372.5 9385.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 1309 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK-100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - FLOWING PASS. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 155 Tape File Start Depth = 9388.000000 Tape File End Depth = 8964.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 79130 datums Tape Subfile: 8 231 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 9 is type: LIS 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: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8980.0 PDK 8991.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9388.0 9400.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 1506 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK-100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 700 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - BASE SEAWATER PASS. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 161 Tape File Start Depth = 9403.000000 Tape File End Depth = 8963.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 80602 datums Tape Subfile: 9 237 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8981.0 PDK 8992.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9390.0 9402.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 1623 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK-100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 700 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - 20 BBLS BORAX AWAY. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 GElS PDK 68 1 CPS 11 ISS PDK 68 1 CPS 12 LS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 i CU 20 SGMB PDK 68 I CU 21 SPD PDK 68 1 F/MN 22 SS PDK 68 1 CPS 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 161 Tape File Start Depth = 9405.000000 Tape File End Depth = 8965.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 119634 datums Tape Subfile: 10 237 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8982.0 PDK 8993.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9390.0 9402.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 1707 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK- 100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - 40 BBLS BORAX AWAY. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 GElS PDK 68 1 CPS 11 ISS PDK 68 1 CPS 12 LS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SPD PDK 68 1 F/MN 22 SS PDK 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) Total Data Records: 161 1018 BYTES * Tape File Start Depth = 9405.000000 Tape File End Depth = 8965.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 121106 datums Tape Subfile: 11 237 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8980.0 PDK 8991.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9392.0 9404.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 1912 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK- 100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - 60 BBLS BORAX AWAY. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 161 Tape File Start Depth = 9407.000000 Tape File End Depth = 8967.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 160138 datums Tape Subfile: 12 237 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8981.0 PDK 8993.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9392.0 9405.0 17-DEC-92 FSYS256 REV:G002 VER:2.0 2002 17-DEC-92 9410.0 9406.0 9000.0 9394.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR CCL CASING COLLAR LOC. TEMP TEMPERATURE PDK PDK- 100 $ TOOL NUMBER 2324XA 2120XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 0.0 9510.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 226.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALI ZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: RAW PDK/GR - 20 BBLS SEAWATER FLUSH. $ CN : BP EXPLORATION WN : S-33 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 0 1 6 6 6 1 1 1 1 6 1 6 0 1 0 0 0 0 6 1 5 6 88 * DATA RECORD (TYPE# 0) Total Data Records: 161 1018 BYTES * Tape File Start Depth = 9408.000000 Tape File End Depth = 8968.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 161610 datums Tape Subfile: 13 237 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 14 is type: LIS 01 **** REEL TRAILER **** 93/ 2/25 01 'RECEIVED MAR 10 1995 Alaska 011 & Gas Cons. Commission Anchorage Tape Subfile: 14 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 25 FEB 93 12:17p Elapsed execution time = 41.41 seconds. SYSTEM RETURN CODE = 0 A~ASKA COH~UT~NC C£NTBR ~mmmmmmm~$~m~mmm~~~ WELL NA~E ~ 8',- 33 (1!-35.1' FIEBD NAME I PRUDHOE BAY BOROUGH ) NORTH SLOPE STATE I ALASKA APl NUMBER I 50-02g~22293"00 REFERENCE NO ~ 92620 ,IS Tape Yeriflcatlon L~st[nq ,chlum. berqer Alaska ComPutinq Center 9-FEB-1993 06:52 **** REEL HEADER **~* S~RVICE NAME = EDIT DATE = 93/02/ 9 ~EEL NAME = 92620 CONTINUATION # = PREVIOUS REEL = COMMENT = BP EXPLORATION,PRUDHOE BA¥,S - 3~ (11-35-~2-12),50-029-22293-00 **** TAPE HEAD£P **** SERVICE N~ME ~ EDIT DATE = 93/02/ 9 ORIGIN = FblC TAPE NAME ~ 92620 CONTINUATION # P~EVIOUS TAPE COMMENT = BP EXPLO~TION,PRUDHOE 8A¥,$ - 33 (~-~5-~2-~2),50-0~9-2~9~-00 TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIREblNE LOGS W~bb NAME = AP! NU~ERI OPERATOR: M N bOGGING CO,.PA ¥: TAP~ CREATION DA'TEl JOB DATA ~,OGGING OPERATOR WITNES ~URF.ACE LOCATION SECTION: TOWNSHIP= ~ANGE: FNS= FSL=' FWL: ~LEVATION(FT FROM MSb O) KELLY BUSHING= DERRICK FLOOR{ GROUND LEVEL~ W~SL CASING RECORD STRING RUN ~ 9R6~0 SIMMONS H. HAYWOOD RUN 2 RUN 3 35 1. 2N J, 639 OPEN ROLE CASING DRILLERS BIT siZE (I~) sIZE (IN) DEPTH eFT) 6.750 7,6.25 90~2.0 PAGE= IS Tape Yertflcation Listing Chlumberger AlasKa Computing Center ]RD STRING P~ODUCTION STRINg REM~RKS~ 9-FEB-19g3 06:52 FIELD ENGINEER'S REMARKS~ 1,O IN RUBBER FIN STANDOFFS USED TO CENTRAtIZE TOOLSTRING, SPIKING ON MfDIUP INDUCTION CURVE AT 9173' ON MAIN PASS IS CAUSED BY TOOL STICKING AS SEEN ON TENSION CURVES, DITF RUN IN COMBINATION WITH SONIC AND NEUTRON TOOLS AFTER SONIC CASING CHECK IS AT END OF REPEAT PASS. ~ATRIX : SANDSTONE, HOLE CORRECTION IS SET TO BIT SIZE. BHS = CASE FOR CNL LOGGED IN CASING. PAGE) ***~ FILE HEADER **** FILE NAME = EDIT ,00! SERVICE : FblC VERSION ~ O01A07 DATE = 93/02/ 9 MAX REC sIZE = 1024 FIbE TYPE = 50 LAST FILE ~' F~bE HEADER FTbE NU~BER~ EDITED CURVES All tOO1 str~nqs~ DEPTH INCREMENT FILE SUMMARY PBU TOOL CODE DTE CNTH , Pe'pt~ 0.5000 and clipped curves~ all runs merqed~ no cased hole data, START DEPTH 9470B,0 95!' .0 9459.0 STOP DEPTH 90 ,0 9022,0 ~]BBBB .0 9444 9426 9425 9414 94~1 9408 9 9~99 99 9425.5 941.3.0 9409.0 9399,0 88 5 ,.088.0 94i~.0 9425.5 9408,5 9408,5 9399.0 9399.0 chlumberger _ aska Comput n~ Center 9-FEB-1993 06:52 PAGE: 9392 9380 9362 9348 9344 934t 9327 9317 9302 9300 9280 9269 9269 9256 92'54 9254 9253 9246 9244 9235 9232 9232 9218 9212 9197 9196 9!76 9167 916 916 9I 9135 9133 9130: 9126 9124 9!111 9106 9090 9086 9085 9046 9044 9043 9034 8999 8986 8977 93902.0 938 .0 9362.0 9348.0 9345.0 9341.0 9327.0 9317.0 9301.5 9301.5 9280.0 9270.0 9269.5 9257.5 9254,0 9254,0 9254,0 9245,5 9245.0 9235,5 9232.5 9234.0 q~32.5 9 18.5 9212,0 9:212,0 9196.5 9196,5 9176,0 9167' 0 9167,0 9161.5 9!61,5 9158.0 9 I56,'0 9135.5 9132,5 9130,5 9!24,5 9124.0 9110,0 9t07,0 9107,0 908~.5 9085'5 9085,5 9045,0 9042.5 9042.5 9045.0 9034,5 9011.5 100.'0 99.0 100,5 ,IS Ta~e Verification L~stin~ ,c~lumber~erAlaska Co~poti~ Ce~er 9-FEB-1993 06:52 PBU TOOL CODE $ ~EMARK$1 THE DEPTH SFb TO GR (CARRYING $ LIS FORMAT DATA ~UN NO'. PASS NO, mERGE TOP MERGE BASE ADJUSTMENTS SHOWN ABOVE REFLECTS DT TO GR (CARRYING ALL OTHER DTE CURVES), ~PHI TO ~R ALL OTHER CNTH CURVES). PAGE: FORMAT SPECIFICATION RECORD SET TYPE m~m~m~mmmmmmmmmmm~mmmmmmm~m~m TYPE REP~ CODE V~LUE mmmmm~lmmmmmmmmmmmmmmmmmm)m~m I 66 0 2 66 0 3 73 ~0 4 66 5 66 6 7 65 9 65 13 66 0 14 65 15 66 68 16 66 0 66 0 NANE SERV UNIT ID DEPT' F? DT BCS US/F G~ BC$ GAPI T~NS BCS LB T'~ND ECS LB IDPH DTm IMPH DTE OHM~ I~O DTE OHMM ILM DTE OHM~ SFL DT~ SP DTE HTE~ DTE 8ERV'ICE API APl AP1 ~P! FILE N[~MB NUMB SIZE REPR PROCESS ORDER # bOG TYPE CbASS MOD NUMB BAMP ELEM CODE (HEX) 599441, O0 000 O0 0 I 1 ! 4 68 0000000000 5 ~4~ ooooo oo o i ~ i 4 ~.~oooooooooo 59~4~OD oooOD o ~ ~, 1 ~ ~. oooooooooo ~41 oo ooooo o 1 i ~ 4 68 oooooooooo ~41 OD ooooD o ~ ~ t 4 68 oooooooooo ~~i OD ooooo o i i i 4 ~ oooooooooo 599441 O0 000O0 0 I ~ I 4 68 0000000000 s~4~loo ooooo o 1 i ~ 4 6~ oooooooooo 599441 O0 000O0 0 1 ! I 4 68 0000000000 s~4~ OD ooooD o 1 ~ 1 4 ~8 oooooooooo s..~xoo ooooo o x ~ ~ ~ ~8 oooooooooo ~.~4~oo ooooo o ~ ~ ~ ~ ~. oooooooooo ,IS Ta~e'Veriflcation L[stXng 9-FEB-1993 06:52 ;chlumberger Alaska Computing Center PAGE~ ID ORDER # bOG TYPE.CLASS MOD NUMB SAMP ~EE~ CODE (HEX) .... ......... ...... ................;;.. RE8 DTE OHMM 599441 O0 ! ! 4 68 0000000 0 NPH! CNTH PU-$ 599441 O0 000 O0 0 t I 1 4 68 0000000000 C~AT CNTH 599441 O0 000 O0 0 i 1 I 4 68 0000000000 N~AT CNTH 599441 O0 000 O0 0 i 1 ! 4 68 0000000000 NCNT CNTH CPS 599441 O0 000 O0 0 ! 1 I 4 68 0000000000 FCNT CNTH CPS 599441 O0 000 O0 0 1 i I 4 68 0000000000 CNTC CNTN CPS 599441 O0 000 O0 0 ! 1 1 4 68 0000000000 CFTC CNTH CPS 599441 O0 000 O0 0 I ! ! 4 68 0000000000 Ib~ DTE MRES DTE NCNT CNTH DEPT, TEND.BC$ ILM,DTE ~RES'DT~ NCNT.CNTH DEPT.' I~M;DT~ NCNT'CNTH TEND.BCS XLM'DTE NCNT,C'NTH DEPT X~M'DT~ NCNT'CNT~ TEND'BCS XL~.DT~ NCN?'CNTH 9516 000 856 :115 =999:250 0 475 -999 250 9500,000 838,902 4.336 0.475 '999.250 9400'000 897.~95 ,564 ~'467 9~gO..O00 1'446 Oo 3461.,I~5 Ooo 974'289 14'64 0,.47~ 4327.815 9100.000 958.498 20,635 0492 5694:000 DT'BC$ !DPH'DT£ SFL,DTE NPHI,CNTH FCNT.CNTH DT;BCS IDPH,DTE SFL'DTE NPH{.CNTH FCNT.CNTH DT,BCS I~DPH'DTE $FL~DTEi NPHI,CNTH FCNT~iCNTH DTBC$ 'IDPH DTE NPHt.iCNTH FCNTi.CNTH DDT BC$ i.~H:DTE '$FLiDT~ NP~! CNTH ~CNT.CNTH -99~.250 GR.BCS -99 .250 IPPH.DTE -99~.2~0 SP'DTE -99 .2 0 CRAT.CNTH -999'250 CNTC.CNTN -999,~50 GR.BCS 4, 25 IMPH.DTE ,999,~15 SP;DTE 50 :CRAT,CNTH 999,250 CNTC.CNTH G~'BC$ 902 SP.,~DTE 19'647 CRAT.CNTH 041 I~PH,DTE ,~2~.298 SP.*DT~ 1324'0'9 ,8~5 CRAT,CNT~ C~TC,C~TH 85'795 G~.BCS DTE 17,325 SP;DT~ ~25;~,3 CRAT'CNTH 1~6~',i19 CNTC*CNT~ , CEA?'CNTH :999.250 .999.250 999.250 -999'250 -999.250 "999.250 . 4,656 -22'438 .999-250 999.250 1~ 672 192 ! 928 4834:750 71.54~ 3,i91 -27'188 ~2'354 3473.500 .2!.697 '584 TEN$.BCS ILD.DTE MTEM.DTE NRAT.CNTH CFTC'CNTH TENS,BCS XLD.DTE MTE~.DTE NRAT'CN?H CFTC.CNTH ISD.DTE ~TE~.DTE N~AT'CNTH CFTC.CNTH TENS. BCS 'ILDDTE ~TEH DTE NRAT CNTH CFTC,CNTH TENS.B I'LD.D~E ~TE~.DTE NRAT.CNTH CFTC'C.NTH TENS'BC$ ILD'DTE MTEM'DT:E N~AT.CNTH cFTC.CNT~ 4325 -999 18 -999 470. 4515, 4565, 186; 4375 000 25O 250 000 992 641 25O 250 882 :00o 00o 981 714 499 25O · 000 794 546 000 063 373 689 000 IS ?eee verification ~istlnq Chlumberqer Ales~e ¢omputinq Center NRES DTE 0,507 NPHI;CNTH NCNT CNTH 1544.000 FCNT.CNTN END OF DATA 9-FEB-1993 06:52 104 -999 -999 55 332 250 IMPH,DTE SP,DTE 503 CRAT,CNTH 156 CNTC,CNTH TEN$.BC8 ILD.DTE NTEM.DTE NRAT.CNTH CFTC,CNTH PAGE{ 4355.000 -999 250 178:338 4,09X 345.789 *~ FILE TRAILER FILE NAME { EDIT .001 SERVICE ~ FLIC VER~lO~ { OO1AO? DATE I 93102/ 9 ~X REC SIZE ~ 1024 FILE TYPE i LO LAST FILE FILE,NAME : EDIT ,002 SERVICE ~ FLIC VER ~ ION: 00iA0? DATE' : 93/02/ 9 F~Lg'TYPE .: LO LASTFiLE I, EDI'TED..:CASED,,,HOLE.,MAIN ~ASS Depth shi'~te:d'end clipped curves PASS NUMBE~{ DEPTH'INCREMENT 0,5000 POU TOOL C00E GRCH C'~TH START, DEPTH 9022' 0 902~o 0 BASELinE DEPTH m~88 0 ~or open h.oleloqs STOP.,DEPTH 804 88867 $999~0 run into casing, DEPTH---------- ,IS Tape Verification Listing ;chlUmberger Alaska Computing Center 9-FEB-1993 06:52 PAGE: 8986°5 8985 5 8977 5 8943 0 8934 o 8925 5 89t6 5 8909 5 8998 5 8862 5 8750 .0 8722 0 $708 5 8687 5 8669 0 8659 0 864? 0 8594 0 8586~ 0 8566 5 8556 5 854.7:5 8539 5 505 842;7 5 8414 5 8396 5 8382 ,0 8367 5 83 6 4 5 8328 0 830! ~0 8283 0 8222 5 8221:0 82!0 0 8 ! ? 8 0 8165 0 8i 5 0 810 ~10', 0 80~: 0 ~0, 0 8986.0 8977.5 :. 100,0 8986.5 8976.0 8955,5 8943,5 8934.5 8925.0 8917.0 891! 5 8898!5 8863 0 8751.0 8722.0 8709'0 8687,0 8669.0 ~659'0 646.0 8596 5 8587:0 8566:5 8557 5 8547 0 02.0 8.484 0 8456~5 8447 0 84320 8427 5 84I 0 839~ 0 8381 5 8367.5 8365.:0 8328,5 8303,.0 8284.0 8223;0 8220.5 82!0,0 8!78,5 8164'0 8!54,5 8103,5 8101,5 809i'0 lO0'O TO OPEN HOLE ~R'AND'¢ASED.HOLE NPHi TO CASED HObE G~ (CARRYING ALb OTHER CNTH CURVES). ,IS TaPe Veri~ication L{stlna ;chlumberger Alaska Computing Center $ FORMAT DATA 9-FEB-1993 06:52 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE ~ 66 0 2 66 0 4 66 t 5 66 6 73 7 65 8 6~ 0 5 9 65 Ft ~! 66 ~ 66 ~I 5 66 68 ~ SET TYPE - CHA~ ~ N~E SERV UNIT: SERVICE APl AP'! API API FiLE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLA~S MOD NUMB SAMP E~EM CODE (HEX) · .00000 GRCH CNTH GAPI 59944:1 O0 000 O0 0 ~ I 1 4 68 0000000000 I O0 000 O0 0 ~ I 4 68 0000000000 NPH! .... CNTH PU-S 59944 CRAT CNTH 59944 O0 000 O0 0 ~ ! I 4 68 00'00000000 NRAT CNTH 59944! O0 000 O0 0 ~ ! I 4 68' 0000000000 FCNT CNTH CPS 599441 O0 000 O0 0 2 ~ I 4 68 0000000000 NCNT CNTH CPS 599441 O0 000 O0 0 2 1 ! 4 68 0000000000 CNTC CNTH ~P$ 599441 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTH ~P$ 599441 O0 000 O0 0 2 ! ! 4 69 0000000000 TENS CNTH LB 599441 O0 000 O0 0 2 ! i 4 6~ 0000000000 TEND CNT8 ~B 599441 O0 000 O0 0 2 ! I 4 6 0000000000 MRE$ CNTH OHM~ 599441 O0 000 O0 0 2 ! I 4 68 0000000000 ~mmm~m~m~mmmmmm~m~mmm~mmmm~m~m~m~mmmm~m~N~~m~mm~m~m~mmmmm~N~~m~~~ IS ?ape Verification Listing chlumhergerAlaska Computing Center 9'FEB-1993 06:52 DEPT, 90~0.000 GRCH,CNTH -999,250 NPHI,CNTH NRAT.CNTH 4.333 CFTC.CNTH 363.025 TEN$.CNTH 4455, 0 TEND,CNTH DEPT. 9OO0.000 GRCH.CNTH 82.369 NPHI.CNTH ~AT.CNTH 5,048 FCNT,CNTH 37~.057 NCNT.CNTH CFTC.CNTH' 370.628 TENS.CNTH 467 .000 TEND.CNTH DEPT. $900.000 GRCH.CNTH 9~.417 NPMI.CNTH N"AT:~NTH 4,296 FCNT.CNT, i~ .969 NCNT.CNT, CFTC NTH 368.969 TEN$.CNTH 4 5.000 TEND.CNTH DEPT. 8900.000 GRCH.CNTH 60,305 NPHI.CNTH NRAT.CN?H 4.005 FCNT.CNTH 312,06] NCNT.CNTH CFTC.CNTH 3~7'000 TENS.CNTH 444~.000 TEND.CNT~ DEPT 9700'000 GRcH~CNT~ 61.879 NPHI CNTH NRAT'CNTH 3.652 FC~T.CNT~ 532,8~3 NCNT~CNTH CFTC:CNTH 556'689 T~N$.CNTH 4~05..000 TEND.CNTH DEPT~,: 8600,000 NEAT'CNTH O0 GRCH,CNTH 54. 4 NPHI'CNTH CFTC,CNTH 59 '000 TENS.CNTH 431~.~09 TEND.CNTH ,400'000 '595 FCNT,CNTH 576, 6 NCNT,CNTH CFTC.CNTH 55 .063 TEN$,CNTH 4155,000 TEHD'CNTH · CFTC,CNTH 340,898 TEN$,CN?H 4 ~0 0 TEND,CNTH D~PT... 8200,.000 GRCH,CNTH 72,7~! NPHf,CNTH NRAT,CNTH 4'334 FCNT,CNTH 337,250 ~CHT*CNTH CwTC,CNTH~ 360'656 TENS.CNTH 40t5,000 TEND,CNTH D~PT,~: 8100 000 GRCH'CNTH 49,2~8 NPHI.,CNTH NRAT,CNTH. 3:892 FCNT,CNTH 438'375 NCNT,CNTH CFTC,CNTH 480.~:09 TENS'CNTH 3935,000 TEND'CNTH DEPT' 8045.000 GRCH.CNTH 45,737 NPHI,CNTH N~AT:'CNTH 3,543. FCNT.CNTH 648.075 NCNT,CNTH CFTC'CNTM 639.36! TENS,CNTH 4045.000 TEND,CNTH END OF DATA 48,778 1675.887 944.592 50,412 1506.595 936,267 47,78! !528,250 1000.563 49,492 i408,500 960,688 37.637 1862,844 995.53! 36'810 02,883 92'563 34'~261 974'414 158~.,418 99..21! 998 342 40,92! 852'~50 1959'i25 1889.~ 961, 0 CRAT.CNTH CNTCCNTH ~RES:CNTH CRAT.CNTH CNTC.CNTH NRES,CNTH CRAToCNTM CNTC.CNTH ~RES.CNTH CRAT.CNTH CNTC,CNTH MRES.CNTH CRAT.CNTH CNTC.CNTH ~RES.CNTH CEAT.CNTH CNTC CNTH CEAT..CNTH CMTC.CN?H MRES'CNTH CRAT,CNTH ~ES.CNTH NTC,CNTH CEAT,CNTH CNTC,CNTH ~RE$.CN?H CRAT,CNTH CNTC,CNTH CRaT'CNT~ cNTC,CNTM MRE~,CNTg PAGEI 4,078 1526.679 0,531 4,168 1437.725 0,531 4,024 ~437,813 0.528 4,063 1337,84~ 0.53 3,467 !81!,875 0,534 3'4~2 1800;063 542 3,282 184~:~004.7 o. 52 4,288 148~,750 ,550 3.647 !749'375 0'565 3,066 1904,078 0,568 Tape Verification Listing ,chlumbergerAlaska Computing Center 9-FEB-1993 06:52 PAGEI I0 FILE NAME ~ EDIT .002 SERVICE : FLIC VERSION : 001A07 DaTE : 93/02/ 9 mAX REC SIZE : 1024 FILF TYPE ~ LO LAST FILE : FILE HAME ~ EDIT .003 VERSION : 00iA07 DaTE : 93/02/ 9 ~AX REC SIZE : lo24~ F~LE TYPE ~ LO LAST FILE ~ FILE ,HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each.run a~d.tool string ~ separate files ToolStrlng #1 fo Sa. dlerochit run presented first, (prlmar¥,~depth control s ~lng used to depth shift the Sadler other main pass strings pev run. interval) followed bY files for RUN NU~BERI OOL STRING NUMBER~ D~PTH INCRE~ENT~ 0.5000 VENDOR TOOI~ CODE START DEPTH BHC 9475.O DTE 9506'0 CML 9457.0 $ LOG HEADER DATA DATE ~OGGED~ SOFTWARE VERSION~ TI~E CIRCULATION ENDED~ TI~E LOGGER ON BOTTO~I TD DRILLER TD LOGGE~(FT): TOP LOG INTERVAL, (FTII BOTTO~ bOG INTERVAL FT) 50GGING SPEED (FPHR)~ TOOL STRING (TOP TO BOTTOM) VENDO~ TOOL CODE TOOL TYPE STOP DEPTH m~,mmmm,4mmmmmmmmm 9022.0 90~2.0 90 2.0 tg-OcT-g~ 5C0-423 95~0. 8045. TOOL NUMBER chlumberqer Alaska ¢omputln~ Center g-FEB-1993 06:52 PAGE: 11 GR CNL BHC DTE DTE $ ~UD ~UD AUXILhIARY HEASURE~ENT TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRO~ BOREHOLE SONIC BOR~HOLE SONIC DUAL INDUCTION DUAL INDUCTION # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH L. OG~ERS CASING DEPTH (FT): E CONDITIONS TYPE: DENSITY (LB/G): VISCOSITY PH{ D bOSS MAXIMUM RECORDED TEMPERATURE (DEAF RESISTIVITY. (OHMS) AT TEMPERATURE ~UD AT ~EASURED, TEMPERATURE (~T ~UD AT BOTTOM HOLE TEmPERATURe' ~UD FILTRATE AT ,UD FILTRATE AT (8,T), ~UD CAKE AT ,UD CAKE AT'{~B. ): NEUTRON TOOL TOOL TYPE (EPITHERHAL OR THER~AL)~ MATRIX DENSITY: HOL~ CORRECTION (IN): ToOL STANDOFF (IN): : F DES ): TCC-B SGC-$A CNC-HA SLC-UA DIC-EB DIS-HB 6.750 9022.0 9022.0 LSND 9°20 41.00 11.40 6 0 ~o460 1~400 2,290 71.0 64,0 62,0 2'65 REMARKS: 1 0 IN RUBBER .,.IN ~TANDOFFS USED TO CENTRALIZE' . T6~LGTRING,~ SPIKING ON ~EDIU~ INDUCTION CURV~ AT 9173' N PASS IS CAUSED BY. TOOL. STICKING AS'SEEN O~ TENSlO p~$~ AT~I~ =~'~ST6~2 6~R ~N IS LIS FORMAT DATA Tape Verification blstlno ehlUmberger AlasKa ¢omDutina Center 9-FEB-1993 06:52 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 4 66 ! 5 66 6 73 7 65 9 65 ~3 66 14 65 FT 0 66 ** SET TYPE - CHAN ......,..............................,..........................,,..,.....,,.,............. NAME SERV UNIT SERVICE API AP1 API AP1 FILE 'NUMB NU .. IZE - P PROCESS ID ~RDER # LOG TYPE CLASS MOD NUMB SiMP ELEM CODE (HEX} DEPT FT 599441 O0 000 00 0 3 ! ~ 4 68 0000000000 DT BHC TT! BMC TT~ BHC TT3 BHC TT4 BHC SP BHC G~ BH ~T~M BHC M~ES BHC HTEN BHC CIDP DT~ IDPH DTE CI~P DTE INPH DTE CILD DTE ILO DT~ CILM DTE IL~ DTE IOOF l~or DTE IIRD DTE IIXD DT~ IIR~ DT~ iiX~ DT~ US/r 59944! O0 US' 599441 O0 US 59944! O0 US 5994.4! O0 US 599441 O0 ~¥ 59944! O0 GAPI 59944t O0 LB 599441 O0 DEGr ~99441 O0 OHMM 599442 O0 LB 59944! O0 ~HO 59944! O0 OHM~ 599442 O0 MMHO 599~.41 O0 OH~ 599 42 O0 MMHO 59944! O0 OHM~ 59944! O0 ~HO 59944! O0 OHM~ 59944~ O0 599442 O0 59944! O0 MMHO 59944~ O0 MMHO 59944! O0 MMHO 59944! O0 MMHO 59944! O0 000 00 0 3 000 00 0 3 000 00 0 3 000 O0 0 3 000 00 0 3 000 00 0 3 000 O0 0 3 000 O0 0 3 000 OO 0 3 000 O0 O 3 0OO O0 0 3 000 O0 0 3 000 O0 0 3 000 O0 0 3 000 O0 0 000 O0 0 3 000 O0 0 3 000 O0 0 3 000 O0 0 o00 O0 0 3 000 O0 0 000 O0 0 3 000 O0 0 3 000 O0 0 000 O0 0 3 ! I 4 68 0000000000 ! ! 4 68 0000000000 ! ! 4 68 0000000000 i ! 4 68 0000000000 ! ! 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 I ! 4 68 0000000000 ! I 4 68 0000000000 I I 4 68 0000000000 i ! 4 68 0000000000 I ! 4 68 0000000000 ! 1 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 ! I 4 68 0000000000 t I 4 68 0000000000 1 ! 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 ! I 4 68 0000000000 I I 4 68 0000000000 12 ,IS Tape Verification Listing ;chlumberger AlasKa Computing Center g-FEB-1993 06:52 PAGE: 13 s;;; ;;;; '"'"" PROCESS ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~~-~~~;;;~~~~~~~~.~..~~;~~;;~.~~~..-~$~L~ DTF 0,, 4, O0 000 O0 0 3 1 0000000000 NV 599441 O0 000 O0 0 3 1 1 4 68 0000000000 SP DTE G~ DTE TENS DTE NTE~ DTE HTEN DTE NPH! CNL RTNR CNL TNPH CNL TNR~ CML NPOR CNL RCNT CN5 RCFT CNL CWTC CNL CFTC CN5 G~ CN5 TENS CNL GAPI 59944! O0 000 O0 LB 59944! O0 000 O0 DEGF 599441 O0 000 O0 OHMM 599441 O0 000 O0 LB 599441 O0 000 O0 PU 599441 O0 000 O0 599441 O0 000 O0 PU 599441 O0 000 O0 599441 O0 000 00 PU 599441 O0 000 O0 CPS 599441 O0 000 O0 CPS 59944! O0 000 00 CPS 59944! O0 000 O0 CPS 599441 00 000 00 GAP! 599441 O0 000 O0 LB 599441 O0 000 O0 OHN~ 599441 O0 000 O0 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 o 0 o ° 1 0 0 3 o 3 ! 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 i 4 68 0000000000 ! 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 ! 4 68 0000000000 ! 4 68 0000000000 DEPT TENS B~C ¢IDP DTE CYbD DTE ]DOF,DTE iIRM.DTE G~.DT~ HTEN;DTE TNR::A*CNL CN?C%CNb DEPT. TT3.BHc TENS.BHC CYDP.DTE C'ILD*.DTE ]DOF.DTE ]IRM;DTE G~,D=TE HTEN.DTE TMRA.CNL RE$.CNL 9529.500 DT*BHC 546'400 TT4'SHC 3010"000 ~TEM*BHC~ 304'359 IDPH;DTE 303.~142 ILD..:DTE 0.000 IMOF~DTE 325'279 IIXM-DTE 10'6'78 TEN$*DTE '315':43~ NPHI;CN~ 2'~28 32:90'~36 CFTC'CN5 ' 0,475 MTEM"CNL .soo'ooo 546'400 TT4'BHC 4470-000 MTE~,BHC 248*440 IDPH-DTE 250'484 I~Di':i:DTE 0'000 IMOF:,DTE' 216.443 IIX~'DTE 10,678 TEN$.DTE 838'902' NP~I.C~5 2.928 NPO:R.C~'b 3290'136 CFTC'CNL 0.475 ~TE~.CNb 85,2~0 TTI,BHC 75,6 0 SP,:BHC ;641 '286 CIMP.,DTE IIRD.DTE 3:5~:8~0 SFLU'DTE: 9~3 RTNR,,.C~b 6 3 RCNT;C'N~ GR'CN~ 6.~ H:TEN.CNL 4 3: 641 0 5: 000 IIRD: ~86' SFLU~ 000 953: RTNR~ 663 RCNT HTEN, BHC ,DTE ,OTE ,DTE , CNL , C N L CNL ~40'800 TT~'B~C 2o.o00 0*4?5 HTEN.BHC 347'856 I~PH,.DTE 349*356 ILM,,DTE 255,131 IIXD.DTE ~4.650 SP;DTE TNPH...CNL ?ENS.CN~ 8 HTENBHC 7.9 . I!×D DTE 9.:0~5 SP DTE 188'6 1 ~RES DT~ 3.1 I TNPH CNL 3468,9~0 RCFT CNL 8 T~N'S 8.9 o'.oo . 10,678 20-000 1094,079 3010,000 370*800 902 4470'000 ?ape Veriflcati. on Llstinq chlumberoer ~las~a Computinq Center 9-FE~-1993 06152 14 DFPT. TT3.BHC TENS.BHC CIDP.D?E ClED.DTE IDOF.DTE I~R~eDTE G~.DTE HTEN,DTE TNRA.CNL DEPT. TT3.SHC TENS,BHC CIDP~DTE CI~D~DT~ G~,DTE HTEN..DTE TNRA,CNL CN?C*,CNb TEN$,BHC CIDPDTE IDOF.DTE IIR~ DTE G~ D'TE HT~ DT~ D~PT, C~DP, DTE C~LD,,DTE IDOF*D'TE IIRM',.DTE CNTC~C,~ ~ES,CNL g400.O00 DT.BHC 75.600 TTI.BHC ~83.200 TT2.BHC 482.600 TT4.BHC 344.000 SP.BHC 47.813 GR.B,C 4495.000 ,TEM.BHC 18:,~94 MR,S.BHC g.l~ ,TEN.~HC 201,338 ID,H.DTE .967 CI~P.OTE 19 . I~PH.DTE ooo . 19.~.. TENS.D?E 4495 000 MTEM.DTE ~8..... MRES.DTE 897,895 NPHI.CNb 19 354 RTNR.CNL 2.040 NPOR.CN~ 20 ~28 RCNT.CN~ 5154.170 ECFT.CNL CFTC.CNb 2473 0SS CR.CN~ 1~.672 !909 485 178 467 9300.000 536,600 4535*000 233,225 236.442 0.000 221-360 71.546 901.446 2.2?9 3762~:239 0,468 9200 000 4565.000 64.414 66.266 0.000 4070 443 O. 475 DT,BMC 83~550 TT4.BHC :eO0 IDPi:DTE , 88 IL *D?E 411,229 IIXM*D?E NPOR*CNL 1,177 CFTC.C~b ~ *186 ~TEM~CNb ,646 DT'BHC e4 O0 TT4.BHC ~69 00 MTE~*BHC 186 94 IDPH,DTE I5 24 ILD.DTE I5 91 i~OF.DTE 0 O0 IIXM,DTE 2 TENS,D?E~ 45~ ::0 7 ;000 CrTC,CNh 17 ~'5~6 MTEM~'CNL ,794 TTI.BHC SP,BHC MRE$,BHC CINP.DTE ClLM.DTE II~D,DTE SFLU;DTE MTE.M.DTE RCNT. GR*CNb HTEN.CNb TTt',SHC SP*BHC MRE$..BHC CINP,DTE CILM,DTE I~nV,VrE S~5U.*DTE ~TE~ DTE' RTNR. CNb RCNT:CNb GR CNb HT~CNb .. 538 000 -270 188 · 468 239~ 377 ~235, 96t 767_ 646 47 i 4t44.. 65] 71 546 901.446 66,:~188 0.475 63,408 66,488 60.843 19~.~20 974.289 TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILM.DTE IIXD.DTE SP,DTE MRE~.DTE TNPH.CN'L RCFT.CNL TEN'8.CNL TT2.BHC GR.BHC HTEN BHC IMPH DTE ~ILM DTE IIXD DTE SP DTE MRE8 ~DTE TNPH b RCFT ~ TEN$.CNL 910:0.:000 461"600 4375'000 42'882 47.630 0.000 44,40'5 65,576 958,498 1'591 54~8,600 0.493 DT.BHC TT4'BHC MTEM:,:BHC IDPH-DTE ILD,DTE IMOF,DTE IIXM,DTE TEN$:,DTE: NPH'I'CNb NPOR'CNL CFTC-CNL ~TEM*CNb 1~*0 .9 0 348 3 T~.BHC: 'BHC MRES.BHC CI~P,DTE IleO.V?g SFLU,DTE ~TE~..DTE RTNR.CNL RC~T.CNb HTE~.CNL 4601400 '3~i000 493 44,823 46i73~ 47~405 30,517 183251 1254 5.576 958.498 HTEN ~: IMPH DTE Ib~:.~TETE II~piDTE MRESDTE TNPM CN5 RCFT.CNL TEN$,CN5 343 19 897 5 5 0 2O 2432 4495 369 7 901 4 4 26 0 25 1611 4535 368 i9 974 15 15 0 25 !768 4565 317 21 "30 0 ! 4 343 43752 ,600 ,672 ,895 .252 618 578 813 467 332 706 000 .600 ,546 ,446 178 238 688 000 000 '320 289 771 040 ~6 .188 475 1119 000 600 , ? 6 3t0 399 ??8 000' ~chlumberger Alaska Computing Center DEPT. TT3.BHC TENS.BHC CIDPoDTE CILD.OTE IDGF.DTE IIR~.DTE G~ DTE HTE~' TN~AeCNL ~RES,CNb DEPT TTliBHC TENS BHC CYDP DTE CILD.DTE IDOF.DTE IIR~*DTE GR.DTE HTE~*DTE ES*CML 9000,000 000 45 646 0 000 -19 366 72 072 g~7 t35 4 604 1488 839 0,512 S946'500 -g99,~50 4365,000 38,863 42,614 0,000 4.044 67'698 t028.240 4,19! 139~'5t9 '5~5 DT.BHC TT4.BHC MTE~.BHC IDPH.DTE ILD.DTE IMOF.DTE IIXM.OTE TEN$.DTE NPHi.CNb NPOR.CNL CFTC.CN~ MTEM.CNb DT~BHC TT4.BHC MTEM,.BHC IDPH.DTE ILD,DTE IMQF*DTE IIXM,DTE TE~Si~DTE ~P~I*CNL ~PO~,CNL CFTC*CNL ~TE~,CNb END OF DATA ** **** FILE. TRAILER FILE NA~E = EDIT ,003 SERVICE : VERSION ,"' !A07 ~aX REC SIZ~ = ~024 FIbE TYPE = LO LRSTFILE= **** FILE HEADER FYLE NAP~ { EDIT .004 SERVICE VE~SI:ON : O01AO? DATE { 93/02/ 9 PAX REC SIZE: I I024 FYL~ TYPE = 60 LASTFI~E FiLE HEADER 9,,FEB-1993 06=52 54 000 307 200 176 126 23 469 21 90B 0 000 4-92 889 ,525 000 65 638 68 381 26 202 76 126 54,600 '999,250 .467 o;o0o .000 - , TTI.BHC SP.BHC MRES.BHC CINP.DTE CILM.DTE IIRD.DTE SFLU.DTE MTEM,OTE RTNR,CNL RCNT*CNL GR,CN6 HTEN.CNb SD. MRES, CIMP. CIb., IIRD' srbU, R?MR, RCNT, HTEN. BHC BHC BHC DTE DTE DTE :DTE CN[, Nb 41~ BO0 :250 0 512 -23 06i -20 286 4! 564 0 599 176.126 $ 167 1541 695 7R. OTR 987 135 -999.250 -I52,250 0.5i5 -1B.762 -26,259 17~.365 4.452 1468,490 .240 TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILM.DTE IIXD,DTE SP.DTE ~RES.DTE T~PH.C~L RCFT.CNL TENS,CNL TT2-BHC HTEN BHC IMPH:DTE IbM.DTE IIXD.DTE SP...DTE ~RES,DTE TNPH,CNL eC?T,C~b TE~S*C~L PAGE= 308.B00 72,072 987,135 1950,000 1950,000 -13 ,250 0 512 67~141 305,656 4525,000 99 '967'' 19 9o 1520, 54, 305, 4365, 250 698 240 000 000 032 250 515 466 5O3 000 15 Tape Verification Listing chlumberqer AlasKa Computinq Center 9-FEB'IV93 06:52 PAGE: 16 RAW OPEN HOLE REPEAT PASSES Curves and loq header data ~or each pass, tool strtnq, and run in separate ~iles. RUN NUMBERI 1 TOO[, STRING HUMBER{ PASS NUMRER: 2 DEPTH INCREMENTS 0,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH BHC OTB $ ~OG HEADER DATA DATE LOGGEDS STOP DEPTH 9475,0 9022.0 994~06.0 9022.0 5'/.0 9022.0 SOFTWARE VERSION: TIME C~RCULA?ION ENDED~ TIME LOGGE~ ON' BOTTOM: TD DRILLER TO LOGGE~(FT)I . TOP LOG INTERVAL (FT): BOTTOM LOG ]NTERVAL (FT){ ~EOGGYNG SPEED (FPHR): GR BHC DTE DTE $ TOOL STRING .(TOP,,TO BOTTON) VENDOR TOOL CODE TOO[, TYPE mm~mm~mmmmmmmm mmmmmmmmm .AUXILblARY MEASUREMENT TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON BOREHOLE SONIC BOREHOLE SONIC DUAL INDUCTION DUAL INDUCTION BOREHObE' AND CASING:DATA .. OPEN HOE, E BiT SIZE (.IN)I DRILLERS CASI,NG DEPTH .(FT)l LOGGERS CASING DEPTH (FT)~ BOREHOLE CONDITIONS MUD TYPEI MUD DENSITY (LB/G)~ ~UD VISCOSITY MUD PHs FLUID bOSS (C31~ ~AXI~U~ RECORDE TEMPERATURE (DEGF RESISTIVITY (OHMM) AT TEMPERATURE~ (:) MUD AT MEASURED TEMPERATURE (~T) ~UD AT BOTTO~ HOLE TE~PEPATU~; ~UD FILTRATE AT 19-0CT-92 5C0-423 2030 s o'o 9516.0 8045'0 9506.0 f800.0 18-OCT-92 19-OCT-92 TOOL NUNBER AMM-AA TCC-B SGC-SA CNC'HA SLC-UA SLS-WA DISHB 6 0 2~. 0 · 022'0 bSND 9.20 .40 I~'4o 1.460 1.400 71.0 64.0 IS T~e Yeri~ication Listino chlumbercjer Alaska Co~-putinq Center 9-FEB-1993 06:52 FILTRATE AT CAKE AT PUD CAKE AT (BHT): NEUTRON ?005 TOOL TYPE (EPITHERHAb O~ THErmAL): .ATRIX~ ~ATRIX DENS~TYI HOLE CORRECTION TOOL STANDOFF (IN): 2,290 62.0 SANDSTONE 2.65 RE,ARKS~ t..0 IN RUBBER FIN STANDOFFS USED TO CENTRALIZE TOOLSTRING. SPIKING ON ~EDIU~ INDUCTION CURVE AT 9173' ON MAIN PASS 'IS CAUSED BY TOOL STICKING AS SEEN ON TENSION CURVES. DITE RUN_IN COMBINATION WITH SONIC. AND NEUTRON TOOLS. AFTER.SONIC CASING CHECK IS AT END OF REPEAT PASS. MATRIX .SANDSTONE, HOLE CORRECTION IS SET~TO BIT SIZE* BHS = CASE FOR CNL LOGGED IN CASING.i $ LIS FORMAT DATA PAGE: 17 DATA FORMAT SPECIFICATION RECORD **':SET TYPE - 6.4EB ** .. .mmmmmmm~mmmmmmmmmmmmmem~~m TYPE REPR CODE VALUE mmmmmmmmmmmmmmmmmmmmmm~)mm~m~* · 2 3 4 5 9 0 66 0 65 65 FI 66 68 66 '! IS ?a~e Yer~icatlon b~st~nQ ,chZumbergerAlaska ComPut~nq Center 9-FEB-1993 06~52 PAGE) 8 $~ SET TYPE - CHAN YD ORDER # bOG TYPE CbA$S MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 599441 O0 000 O0 0 4 ! 1 4 be 0000000000 DT BHR US/F 59944! O0 000 O0 0 4 1 1 4 68 0000000000 ?Ti BHR US 599441 O0 000 O0 0 4 1 1 4 6e 0000000000 TT2 BHR US 59944! O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHR US 599441 O0 000 O0 0 4 ! ! 4 68 0000000000 TT4 8~R US 599441 O0 000 O0 0 4 ! I 4 68 0000000000 SP BHR MV 599441 O0 000 O0 0 4 1 ! 4 68 0000000000 G~ BHR OiPI 59944i O0 000 O0 0 4 i 1 4 68 0000000000 TENS BNR bB 599441 O0 000 O0 0 4 1 ! 4 68 0000000000 MTE~ B.R DEGF 599441 O0 000 O0 0 4 ! I 4 68 0000660000 MAES BHR OHMM 599441 O0 000 O0 0 4 ! 1 4 68 0000000000 HTEN BHR bB 599441 O0 000 O0 0 4 ! i 4 68 0000000000 ¢ lDO DTe .MHO 599441 O0 000 O0 0 4 ! I 4 68 000o000000 IDPH DTR OHNN 59944i O0 000 O0 0 4 i I 4 68 0000000000 CIMP DTR MMHO 599441 O0 000 O0 0 4 ! I 4 68 0000000000 IMPH DTR OHMM 59944i O0 000 O0 0 4 ! I 4 68 0000000000 CZUO vmm MMHO 59944i O0 000 O0 0 4 I 1 4 68 0000000000 'iLD DTR OHM~ 599441 O0 000 O0 0 4 1 1 4 68 0000000000 c~M umn .MHO 599441 OD ooo OD o 4 1 I 4 68 oooooooooo Ib~ DTR OH~ 59944! O0 000 O0 0 4 ~i i 4 68 0000000000 DOt PTA 599441 O0 000 O0 0 4 I 1 4 68 0000000000 I~Or DTR 59944! O0 000 O0 0 4 i i 4 68 0000000000 lind DTR MMHO 59944! O0 000 O0 0 4 ! 1 4 68 0000000000 IIXD DTR MMHO 599441 O0 000 O0 0 4 1 ! 4 68 0000000000 0 IIR~ DTR M.,O 599441 O0 000 OD o 4 I]X" DTR .MHO 59944! O0 000 O0 0 4 I ! 4 68 000 SFbO DTR OHM. $99441 O0 000 O0 0 4 ! 1 4 68 0000000000 SP D?R .V 599441 O0 000 O0 0 4 I 1 4 68 0000000000 G. PTA, GAPI 599441 O0 000 O0 0 4 ! 1 4 68 0000000000 TENS DTR 599441 O0 000 O0 0 .4 ! I 4 68 0000000000 MTEM DTR DEGF 59944! O0 000 O0 0 4 1 ! 4 68 0000000000 ,RES'DTR OHMM 599441 O0 000 O0 0 4 ! ! 4 68 0000000000 HTE~ DTR:, bB 599441 O0 000 O0 0 4 1 i 4 68 0000000000 NPH! CNA PU 59944! O0 000 O0 0 4 1. I 4 68 0000000000 .TNR cnn 599441 O0 000 O0 0 4 I I 4 68 0000000000 TNPH cnn PU 599441 O0 000 oo 0 4 ! 1 4 68 0000060000 T~R~CNR 599441 O0 000 O0 0 4 1 t 4 68 0000000000 NPORCNR PU 59944! O0 000 oo 0 4 I I 4 68 0000000000 .CNT CNR~ CPS 5994,4~ O0 000 O0 0 4 i ! 4 68 0000000000 RCFT CN, CPS 59944, O0 000 O0 0 4 .1 ! 4 68 0000000000 CNTC CNn CPS 59944i O0 000 O0 0 4 I I 4 68 0000000000 CFTC CN, CPS 599441 O0 000 oo 0 4 ! ! 4 68 0000000000 GR CNn GAPI 5994.4! O0 000 O0 0 4 I i 4 68 0000000000 TENS CNA LB 59944i O0 000 O0 0 4 I ! 4 68 0000000000 ~:RES C:N, OHM~ 599441 O0 000 O0 0 4 I .1 4 68 0000000000 MTE, DEGF 599441 O0 000 O0 0 4 ! i 4 68 0000000000 ,~TEN CNR:: bB 599441 O0 000 O0 0 4 I 1 4 68 0000000000 ,IS TaPe Veri~lcatlon bist~ng ;chlumberger Alaska Computinq DgPT. TT3.BHR TEN$.BHR CXDP.DTR CIbD.DTR IDOF.DTR IIRM,DTR HTEN.DTR TNEA.CNR CNTC,CNR M~ES.CNR DEPT' ?T~'BHR TFN~,BHR, C~DPD?R: IDOF DTR~ I)EP DTR" GR DTR HTEN DTR TflRA CNR CNTC CNR MRE8 CNRi DEPT.~i TT3oBHR TENS,BHR: CIDP'DTR: ¢ILD.DTR IDOF.DTR IIRM D?R GE DTR HTEN DTR TNRACNR CNTC CNR MRES CNR ?T3.BHR T~NS'BHR CXDPjDTR CibD.DTR XDOF,DTR XIR~.DTR G~'DTR HTEN.DTR TNRA.CNR CNTC.CNE 9521.000 545.200 3890,000 304,999 303,3?3 0 O0 53.389 470.296 2.541 3169.255 0.466 9500,000 545,200 4535,000 260'209 262*119 0'000 250.,6~7 53.389 255 940:0.000 479'~00 4460,000 ! .643' 19 203 900 ,36'1 4950.462 .073 0o:.ooo 536;800 4495'000 2.40,626 244,378 0.000 225'64~ 68.'49 966.'~7! ~209 .3941,t12 0'46~ Center DT.BHR TT4.BHR MTEM.BHR IDPH.DTR IIXM.DTR TENS, DTR NPOR.CNR CFT~.CNR MTEM.CNR DT BHR T?4:BHR MTEM,BHR 1DPH~D?R IbD,D?R IHOF"DTE IIXM.DTR TBN$'DTR NPHI.CNR NPOR'CNE CFTC.CNR DT':BHR ?T4.BHR MTEM~BHR IDPH,DTR ~D'DTE IMQF'DTR iIX~'D?R TEN DTR NPOR'CNR CrTC,CNR MTEM,CNR DT~B~R TT4,BHR MTEM,BHE IDpH~DTE IbDDTR I~OFi.DTE IIX~.DTR TEN$~DTE NPHI CNR NPOE CFTC'NB 9-FEB-1993 06:52 85.500 373,600 188,946 3.279 3 296 0 000 35 248 3890 000 28 842 28 660 1260 756 188 946 S 500 815 000 1260756 188946 74 900 38.400 1164 2~ ooo 220 4460 090 18 491 987 190 405 ~3,300 70,000 ~90.:013 4:'i56 4.092 0,000 20'895 4495;000 24~2B3 1730,928 190,013 TTX,BHR SPeBHR MRES,BHR CIMP, DTR CILM,DTR IIED,DTR SFLU'DTR MTEM.DTR RTNR,CNR RCNT.CNR GR,CNR HTEN.CNR CXM DTR CILM, DTR IIRD.DTR SFLU. DTR .~TEM, DTE RTNR:CNR RCNT CNR GR:CNR HTENCNR TTI.BHR SP:'BHR MRE&~BHR' C~MP~DTR CILM,DT:R XIRD;DTR SFLU,DTR MTEM.,DTR RTNR'~NR ECNT'CNR ~R,CNR HTEN,CNR TTI.~HR SP,BHR ~RES,BHR Ci:~P"OTR CXLM'DTR IXRD'DTR SFLU,DTR MTEM,:DTR RTNR.;CNR RCNT,CNR GR'CNR HT~N'¢NR 542.000 -20.000 0.466 345.352 346.334 ° 255 95 2 5 188 6 334!'460 9 855 =4~-:.56~ '670 ,,243 1~0'405 1':899 0.36! 536 80O 243 240 6 2.2~6 425~,!63 .6~,497 96 .771 TT2 GR HTEN IMPH IbM IIXD TNPH RCFT TENS TT2 HTEN X~PH ItXO TNPH RCFT TENS TT2 GR HTEN IMPH IbM IIXD SP MRES TNPH RCFT TENS T'~2R HTEN IMPH IIXO ~RES TNPH RCFT .BHR ,BHR .BHR .DTR .DTR .DTR .DTR .CNR .CNR .CNR BHR ,DTR ,DTR .D~R 'DTR .CNR ,CNE ,CNR .BHR .BHR ,BHR 'DTR ,O~E jDTR .DTR .DTR "CNR 'CNR .CNR ,,BHR .BHR .BHR .DTR .DTR ..DTR *DTR .C R .CNR 'CNR PAGEI 371. 53, 470. 2. 2. 47, -20. O. 12~7. 3890. 37~ 53 855 3 3 0 1217 4535 340 19 900 4 5 34 '"45 0 18 2593 4460 373 4, O~ 25, 1716, 4495~ 6OO 389 296 896 887 894 000 466 660 063 000 6O0 389 764 906 735 869 688 466 660 063 000 000 20.3 361 3OO 630 563 462 .866 536 000 200 497 771 113 156 582 625 462 052 083 000 19 ,IS Ta~e Veritication Listi~o ;chlumberqer AlasRa ComPutlnq Center 9-FEB-1993 06:52 PAGEI 2O DEPT. TT3.BHR TENS.BMR CIDP.DTR CILD.DTR IDOF,DTR IIR~.DTR OR,DTR H~EN.DTR TNRA.CNR- CNTC.CNR MRE$*CNR DEPT. TENS.BHR CIDP.DTR CILD'DTR IDQF.DTR IIRM.DTR GR.DTR HTE~.DTR TNR~.CNR CNTC'CNR DEPT. .TT3.BHR TEN$.BHR CiL,:DTR' IDOF.*DTR IIRM.DTR :G~,DTR HTEN*DTR TN~*CNR CNTC,CNR ~RES-CNR D~PT, CIDP'DT~ CILD,DTR IDOF.DT~ G~*DTR HTE~..DT~ T:NRA*CNR CNTC.CNR 9200,000 536.800 449 O0 68,273 :ooo 19.I0! 1003, 92 425 426 469 9100 000 4 9 200 43~0 000 42 322 46 800 0 000 43 990 62 ?96 ~08 682 I 547 5566 958 0.486 *600 4650 000 39 924 42 695 O 000 1464 66 0,~504 8900,.000 416~400 4370,000 38"157 40'254 . 0,000 '34,749 65~867 988.47] 145':,943 DT.BHR 85.000 TTI.BHR 533.600 - .ooo DPH.DTR 15 4 CINP.DTR 62.161 ILD.DTR 14.647 CILM,DTR 66.612 IMOF.DTR IIRD,DTR 62.338 IIXM.DTR 16.993 TT2.BHR GR.BHR HTEN.BHR IMPH.DTR ILM.DTR TEN$.DTR NPHI.CNR NPOR.CNR CFTC.CNR MTEN,CNR DT*BHR TT4.BHR MTE~.BHR IDPH.DTR ILD'DTR IMOF.;DTR iIXM.DTR TENS'DTR NPHI,CNR NPOR.CNR CFTC-CNR MT~M.CN~ DT~BHR TT4.BHR MTEM*BHR IDPH;DTR ILD.DTR IMOF'DTR I~XM~DTR TEN$,:DTR NPH!-CNR NPOR~CNR CFTC*CNR MT~M*CNR~ DT*BHR' TT4,BHR MTEM'BHR TDPH,DTR .ILD*DTR IMOF,DTR IIX~.,:DTR TEN$~DTR NPOR,C'NR CFTC,CNR ~TEM.CNR 0o000 2 2 189, 51 69,350 3~9'047 18~.6°° ooo 11.691 4350 ooo 13 93 185 047 64,600 394;400 179,i88 .~5,047 · 0;:000 -93;099 4650;000 718 3~2.84q 19'i88 5 '?oo 3~1400 176o908 26,208 24,842 6!6 SFLU,DTR MTEM.DTR RTNR.CNR RCNT,CNR GR,CNR HTEN,CNR TT1.BHR $~!BHR MRE :BHR CIMP,DTR CILM.DTR IIRD,DTR SFLU,DTR MTEM.DTR RTNR'CNR RCNT.CNR GR.CNR HTEN.CNR TT!..,.BMR SP.BHR MRES'BHR CI~P.,'DTR CXLM,DTR IIRD,DTR SFLU,DTR MTE~,DTR RTNR,CNR GR'CNR HTEN.CNR TT!,BHR SP*BHR :M~E$,BHR CI~P;.DTR CIL~.DTR I!~D.,DTR SFbU.DTR MT~*DTR RTNR;CNR RCNT.CNR MTEN.CNR IIXD.DTR SP.DTR 188.65i MRE$.DTR 2.47~ TNPH.CNRR 4336,14 RCFT,CN 19.10! T~NS.CNR I003.092 - 625 486 42 203 46 292 47 !54 31 475 185 047 1 662 5960 914 62 796 808 682 415'200 "99'500 0.504 - 3"904 ' 1,359 !9,107 0.578 179.!88 4.667 157~.:991 7 '026 976.809 415'600 -3~'640 1,564 98 ,473 TT2.BHR GR.BHR HTEN.BHR IMPH.DTR ILM.DTR IIXD.DTR SP.DTR ~RES.DTR TNPH.CNR RCFT,CN~ TENS'CNR TT2iBHR HTEN BHR I~PH DTR IIXD DTR SP DTR MRES DTR TNPH CNR RCFT CNR TENS CNR TT2BHR GR BHR HTEN BHR i~PH DTR IIXD DTR SP DTR ~RB$ DTR TNPHCN9 RCFT CNR 367. 19. 100]. 16. 15. 6. o: 24. 1859, 4495. 'ii¸ 808 23 43 259, 72' 9?6' 950. ~950' 0 284 4650 307 1950 1950 14 ~?0 600 101 092 087 012 784 000 469 965 347 000 8OO 796 682 695 602 649 625 486 838 600 026 809 000 000 634 500 504 0~4 000 600 86"/ 4'/3 000 000 8~0 750 ?3O 234 000 .I8 uTa~e Verification Listinq ~¢hl m erqer lasKa Computing Center 9-FEB-1993 06:52 PAGE) DEPT. TT3.BHR TEN$.BHR CIDP.DTR CILD.DTR IDQF.DTR IIRM,DTR GR.DTR HTE~.DTR TNRA.CNR CNTC.CNR MRES,CNR DEPT. TT3.BHR TENS.BHR CIDP.DTR CILD.DTR IDOF..DTR IIR~,DTR GR.DTR HTEN.DTR TNRA.CNR CNTC.CNR MRES,CNR DT.BHR 54.900 BHR ~. TT2'BHR 306. BOO 998 867 44~,~ MTEM,BHR 173,602 ,RE$,BHR ) ,) i~EN. , IDPH DTR 32 768 CI.P.DTR ~ ~ HT .BH~ .955 · o . . PM.DT~ 1950.000 o.ooo o ooo i364.386 CFTC.CNR 30~ 322 GR.CNR 6~:955 TENS.CNR 4405,000 0.522 MTEM.CNR 17~ 609 HTEN.CNR 99 867 8747.000 DT.BHR 54 -999.250 TT4-BHR -999 4295.000 MTEM.BHR 17 30,648 IDPH.DTR 3~ 56.371 ILD*DTR 17 0.000 IMOF~DTR 0 '41,374 IIX",DTR ~ 69.343 TENS, DTR ~ 967.~20 NPHI,CNR ~ :198 NPOR.'CNR 5 14~:761 CFTC-CNR 3~g 0'525 NT£~r. CNR J 2 5O ~50 ?~o ooo 604 ooo ! 99 63:t TTi BHR SP BHR MAES BHR CIMPDTR CibM DTR IIRD DTR SFLU DTR MTEM DTR RTNR CNR RCNT,CNR GR,CNR HTEN~CNR -999'250 ? = 0'525 '90,574 ILM.DTR 46.329 IIXD.DTR 0,455 SP.DTR ~7~-63~ ~RES.DT~ TN~.CNR 1428:~4 RCF?.CNR 69,~43 TE'NS*CNR 967, 20 -999 250 69 343 96 195~ !20 000 1950 000 -20 087 -B7 563 0 525 54 140 292 823 4285 000 END OF DATA 21 FILE, NAME ~'EDIT ,004 SERVICE .I FL!C VERSION ~ OOIR07 ~,x REC s~ZE ~ ~024 FILE TYPE .' bO **** F'ILE HEADER FILE:NAME: I EDIT ,005 $~RVICE VERSION ~ O0:lA07 DAT~ ~ 913/02/ 9 MaX AEC' SIZE I ~0~4 FIL~ TYPE ~ LO L~ST FILE FILE HEADER FILE NUMBER 5 ChlumbergerAl. aska Computing Center 9-FEB-lg93 06:52 PAGEt 22 Curves'and log header data for open hole logs run into casing. RUN NUNBER~ TOOL STRING NUMBERS PASS NUMBER) DEPTH INCREMENT= -.5000 F~LE SUMMARY VENDOR.TOOL CODE START DEPTH -...-.....- 9022.0 $ LOG HEADER DATA DATE LOGGED= SOFTWARE VERSION= TIME CIRCULATION ENDED) TIME LOGGER ON BOTTOM{ TD DR~ELER TD LOGGER(FT)) TOP LOG INTERVAL (FT)~ POTTOM DOG iNTERVAL bOGGING SPEED (FPHR)) STOP DEPTH 8045,0 ToOk. STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL.TYPE AUXXDLXARY MEASUREMENT TELEMETRY CARTRIDGE BHC BHC DTE DTE $ GAMMA RAY COMPENSATED NEUTRON BOREHOLE SONIC BOREHOLE SONIC DUAL I~DUCTION DUAL INDUCTION BDREHOLE AND CASING DATA BOREH0bE. CONDITIONS MUD TYPE) MUD DENSI'TY MUD VISCOSITY MUD PHS F~UID bOSS (C3.)) N~XX~UM. RECORDED TEMPERATURE (DEGF)=E F ' RESISTIVITY (OHMM) AT TE'HPERATURE (D G MUD AT MEASURED:.TE~PERA~URE MUD AT BOTTO~ HOLE TEMP'£~ATURE (BHT)~ MUD FIbTRATE AT ~UD FILTRATE AT (BHT)= MUD CAKE AT ]g-OcT-g2 5 0-423 20C30 25t 9510.0 6 0 9506 0 leoo.6 18-OCT-92 ! g-OCT-g2 T00b NUMBER TCC-B SGC-SA CNC-HA SLC-UA SDS-WA DIC-EB 6 75O 9022:0 9,20 41,00 11,40 6;40 192,0 .1,460 1,400 2,290 64.0 62,0 ,IS Tape Verification Listing :ehlUmberger-Alaska Computino Center 9-FEB-lg93 06:52 # LIS MUD CAKE AT NEUTRON TOOL TOOL TYPE (EPITHERMAL MATRIXI MATRIX DENSZTYI HOLE CORRECTION TOOL STANDOFF (IN)~ REMARKSl OR THER~AL)I SANDSTONE 5.65 I'0 IN RUBBER FIN STANDOFFS USED TO CENTRALIZE TOOLSTRING SPIKING ON MEDIU~ INDUCTXON CURVE AT 9173' ON MAIN PA~$ 15 CAUSED BY TOOL STICKING AS SEEN ON TENSION CURVES,: DITE RUN IN COMBINATION WITH SONIC AND NEUTRON TOOLS. AFTER SONIC CASING CHECK IS AT END O~ REPEAT PASS' ~ATRIX m.SANDSTONE HOLE CORRECTION IS SET TO BIT SIZE. 8HS - CASE FOR'CNL LOGGED IN CASING. $ FORMAT DATA PAGEI 23 DATA FORMAT SPECIFICATION RECORD *~.$ET TYPE TYPE ,REPR CODE V~LUE 1' 66 0 2 66 0 3 73 60 4 66 i 9 65 ! 66 17 I~ 68 13 66 0 ii 65 FT 15 66 68 16 66 I 0 66 ! ~ SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl APl ~P! FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 599441 00 000 00 0 5 ! 1' 4 68 0000000000 NPH! CSG PU 59944! 00 000 00 0 5 ! ! 4 68 0000000000 Is ?e~e verification bistin~ ,chlUmbergerAlasKa Computing Center 9-F~B-1993 06:52 PAGE{ mmmm~mmmmmmmmmmmmmmmmm~m~mmm~mm mmmmmmm~S~m~ss~ssmmmm~mSmm{mmmmmm~m#mmmmmmmmmmmmmmsmmmm NRME 8ERV UNIT SERVICE APl APl apl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUNS S{MP ELEM CODE (HEX) mmmmmmmmm~mmmmmmmm~m~m~mm~mmmmmmmmm~m~mm~~m~m~mmmmmmmmm~mmmmmmm~m~m~mmmm~mmM~mmm RTN~ CTG 59944! O0 000 O0 0 5 1 I 4 68 0000000000 TNPH CSG PU 599441 O0 000 O0 0 5 ! 1 4 68 0000000000 TNRA CSG 59944! O0 000 O0 0 5 ! ! 4 68 0000000000 NPOR CSG PU 59944! O0 000 O0 0 5 ! I 4 68 0000000000 RCNT CTG, CPS 599441 O0 000 O0 0 5 1 I 4 68 0000000000 RCFT CSG CPS 599441 00 000 O0 0 5 1 1 4 68 0000000000 CNTC CSG CPS 599441 O0 000 O0 0 5 1 ! 4 68 0000000000 CFTC CSG CPS 599441 O0 000 O0 0 5 ! 1 4 68 0000000000 G~ CSG GAPI 599441 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CSG LB 599441 00 000 00 0 5 { 1 4 68 0000000000 MRES CSG OHMM 59944! O0 000 O0 0 5 I ! 4 68 0000000000 MTEM CSG DEGF 599441 O0 000 O0 0 5 ! ! 4 68 0000000000 HTEN CSG LB 59944! 00 000 O0 0 5 ! ~ 4 68 0000000000 mm~mmmmm~mmm~mmmmmmmm#~mmmm~mmmmmmmmmmmmmmmmmmmmmm#mmmmmm~mmmmmmmmmmmm~mm~mmmm#mmm~#mm~m 24 DEPT. CNTC.CTG~ MRES,CSG DEPT CNTC CSG ~RES CSG CRTCCSG MRES,CSG DEPT. TNRA*CsG CNTC'CS¢ ~RES.CSG DEPT.~ T~RA.eCSG CNTC.CS~ DEPT~ TNRA,CsG. 9075.000 4.078 1503.534 0.:53! 9000,000 4.i124 1485.603 0'531 8900,000 4' 95 1425:~64 0'528 BBO0'O00 . 50 8700~000 3,489' 182!,702 0'534 ,6oo oOo 3'436 1721'259 02539 NPHI CSG NPORiCSG CFTC CSG MTE~.CSG NPHI,CSG NPOR,CSG CFTC,CSG MTE~,CSG NPOR:~s~ CFTC SG NP Z CS NPOR[CS CFTC CSG ~TE~.iCSG NP~! CSG NPOR, CSG CFTC~CSG NPH'I'CSG NPOR,CSG CFTC,CSt ~T~.CSG 48,~8 RTNR,CSG 46. 6 RCNT.CSG 375,I59 GR'CSG 174,330 HTEN.CSG 49,616 RTNR.CSG 46.66 3~9.*; 9~ RCNT,CTG 30 GR.CSG {74. HTEN*CSG 49.090 RTNR.,CSG 46,68 RCNT' 4~7 CSG 363' GR.,CSG 174,83.3 HTEN*CSG 50'09 44'611 RTNR. SG RCNT'~$G 342.:2,! !73.799 38.030 ~TNR,CSG 34,559 PCNT.~CSG 563,988 GR*CSG !72.677 HTE~.CSG · , i !54 RCNT,CSG l.! GR'CSG 74 '5 655.652 4 83 41250 305 96 862 3 625 1866 394 1753.757 54'286 ~0~7'44! TNPH CSG ~CFT:CSG TENS.CSG TNPH"CSG RCFT.CSG TENS.CSG TNPH.CTG RCFT~CSG TENS*CSG TNPH.,~SG RCFT. SG TENS.CSG TNp,.CsG RCFT:'CSG TNPH. SG RCFT.~$~ TE~S.CSG 46..176 362'157 2470.000 48.396 361'767 4670,000 3442854 4425,000 56 44'48i 344' 4340,000 : 33, 183 528.,,89 4205,000 33.73~ 536,078 4205.000 Tape Verification bXstlng :hlumbergerAlaska Computing Center 9-FEB-199~ 06:52 DEP?, TNRR,CSG CNTC,CSG. DEPT TNRR:CSG ~ES SG DEPT., T~RA.CSG CNTC.,CSG MRES,CSG DEPT. TNRR'CSG ¢~TC.CSG DEPT', T~RR,CSG CNTC:.CSG ~RES,CSG D~T':. TNRA.CSG 8500.000 NPHI.¢SG 32.812 ETI~R,CSG 3.471 t8t: CFTC.CSG 595,333 GA,eCG 54.114 0.542 MTEMoCSG 169.612 HTEN.CSG 992.101 8400,000 NPHI.CSG 34,059 RTNR,CSG 3,286 .919 CFTC.CSG , GR,CSG 48.555 .547 MTE.~.CSG 68. 84 MTEN,CSG 984.069 8300,000 NPHX.CSG 49.573 RTNR.CSG 4.684 4.122 NPOR.CSG 44.402 RCNT,CSG 1597 672 1458.782 CFTC.CSG 363.244 GR,CSG 70'161 0,551 MTE~,CSG 166.412 HTEN,CSG 939:324 8200,000 NPHX~SG 54,441 RTNR CSG 4.095 4.389 NPDR.~SG 49,909 RCNT:CSG 1475,772 1474'.4.57 CFTC,CSG 362.768 GR.CSG 72.771 0,560 MTEM-CSG 164,289 HTEN,CSG 998.132 8100.000 NPHI:,CSG 42.848 "TNR.CS~ 4.]20 1732 0 CFTC-CSG 466,788 GR,CSG 49 ~68 0,565 MTE~,CSG !62,970 HTE~.,CSG 973:_14 3,046 NPOR'CSG ,78i RCNT"CSG 20'2 .5 7 · i904,070 CFT¢,.CSG 6~ ,44! GR:.CSG 46-307 0,569 MTEff'CSG 162,069 HTEN,CSG 938~'i39 END OF DATA TNPH.CSG TEMS SG TNPH.CSG RCFT.CSG TENS.CSG TNPH.CSG RCFT.CSG TENS.CSG TNPH.CSG RCFT.CSG TENS.CSG TNPH.CSG RCFT.CSG T~NS,CSG TNP~.C$~ RCFT,C$~ TENS,CS~ PAGEI 25 30.485 555.264 4310.000 31.445 581.542 4170.000 46.318 380.285 4075.000 47.153 325,802 4015,000 41.176 482 915 3935:000 652.5 4045,000 ****. FILE:TRAILER· ****. FILE NAME : EDIT ,005 SERVICE I FLIC .. VERSION ~ O01A07 DATE ~ 93/02/ 9 .aX REC<:SIZE : 1024 rILE~TYPE ' ~ LO LAST FXLE : **** TAPE TR~iL~ **** SERVICE NA~E ~ EDIT DAYE ~ 93/02/ 9 TAPE NAME : 92620 CONTINUATION # ~' I PREVIOUS TAPE ~. COMMENT : BP EXPLORATiON,P~UDHOE BAY,$ . 3¸3 ( 11-35-12-] 2) ,50-029-22293-00 IS Tape Verification bist~no chlumberger Alaska ComPuting Center 9-FEB-1993 06:52 PAGEt 26 · ~*~ REEL ?RAZLER SERVICE NAME : EDIT DATE : 93/02/ 9 ORIGIN : FbIC R~EL ~AME : 92620 CONTINUATION # PREVIOUS REEb