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Home My WebLink About202-192MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 8 Township: 10N Range: 15E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 12,580 ft MD Lease No.: ADL0028329 Operator Rep: Suspend: P&A: XXX Conductor: 20" O.D. Shoe@ 125 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2734 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 11067 Feet Csg Cut@ Feet Liner:3.5" x 3.19" x 3.88"O.D. Shoe@ 12580 Feet Csg Cut@ Feet Tubing: 5.5" x 4.5" O.D. Tail@ 10593 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 11,000 ft 10,214 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2710 2629 2602 IA 489 490 489 OA 80 80 80 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Reservoir plug; isolate production casing leaksprep for redrill. Set down with 200bls tool string. MITT: Pretest Pressures = T/I/O 1218/490/80; pumped 2.1bbls, returned 1.7bbls. January 15, 2025 Brian Bixby Well Bore Plug & Abandonment PBU 01-12A Hilcorp North Slope Inc. PTD 2021920; Sundry 324-596 none Test Data: P Casing Removal: Andres Ponti Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0115_Plug_Verification_PBU_01-12A_bb 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 99 999 999 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.03 14:13:45 -09'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 01-12A Reservoir P&A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-192 50-029-20269-01-00 ADL 0028328 12580 Surface Production Liner 9145 2691 11025 2022 11000 13-3/8" 9-5/8" 3-1/2"x3-3/16"x2-7/8" 8647 43 - 2734 42 - 11067 10558 - 12580 2400 43 - 2734 42 - 8690 8359 - 9145 none 2670 4760 11160 11000 , 11736 5380 6870 10570 11595 - 12428 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 21 - 105938761 - 9022 Conductor 80 20" 45 - 125 45 - 125 1530 520 4-1/2" TIW HBBP-T, 5-1/2" Baker SAB No SSSV 10537 , 10664 8346 , 8428 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 10/23/24 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:06 am, Oct 14, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.10.10 13:58:02 - 08'00' Bo York (1248) 324-596 MGR31OCT24 * AOGCC to witness pressure test to 2500 psi and slickline tag of reservoir abandonment plug w/ TOC at minimum depth of 4-1/2" tubing tail 10,794' MD. SFD 10/23/2024 10-407 DSR-10/14/24 , ADL0028329 SFD, ADL 0028329 SFD JLC 11/1/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.11.01 09:17:13 -08'00'11/01/24 RBDMS JSB 110124 RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Well Name:01-12A Permit to Drill:202192 Current Status:Producer, Not Operable API Number:50-029-20269-01 Estimated Start Date:10/23/2024 Estimated Duration:6days Regulatory Contact:Carrie Janowski 907-575-7336 First Call Engineer:Dave Bjork 907 440-0331 Second Call Engineer:Eric Dickerman 307 250-4013 Current Bottom Hole Pressure:3300 psi @ 8,800’ TVD (average BHP at DS01) Max. Anticipated Surface Pressure:2400 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:100 psi Min ID:2.377” @ 11,139’ MD Max Angle:39 deg @ 11,284’ MD Well History: 01-12 was drilled in Dec 1977, worked over in 1996 and CTD sidetracked in 2002. A second coil sidetrack was planned but the well failed screening. The 1977 vintage production casing has two leakpoints at 3,650ft and 6,050ft that leak a combined 2.4bpm at 1,000-psi. We would like to abandon the reservoir section, cement up the production casing and cut the tubing in preparation for a rotary sidetrack with a high kick off point at ~2,900ft. The sidetrack will be the subject of a different sundry. Justification for Reservoir P&A: In 2023, 01-12A was identified as a donor candidate for a CTD sidetrack. Unfortunately, it failed pre rig screening due to multiple PC leaks. A rotary sidetrack with a high kick outwill now exploit the target. A reservoir P&A is required in preparation for the Hilcorp Innovation rig to drill a rotary sidetrack. Objectives: The intent of this program is to perform a reservoir P&A of the well per 20 AAC 25.112, isolate the PC leaks and cut TBG in preparation for a rotary sidetrack with planned KOP @ ~2,900’ MD. The original wellbore was drilled in 1977 utilizing a 2 string casing design. The 9-5/8” production casing was cemented with 765sx (157bbls) of G cement. Returns and lift pressures are not noted in the daily drilling reports nor on the IADC reports. A CBL was not ran. The floats are reported to have held and excessive cement was not found inside the 9-5/8” during a cleanout run. A 15% washout is assumed in the cementing calculations. 3.1 bbls are contained in the shoe tract. The annular capacity of the 12-1/4” OH x 9-5/8” casing is 0.0558 bbls/ft. Correcting for a 15% washout yields 0.0641bbls/ft annular capacity and a top of cement at 9,589ft MD. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. T/ Sag River 9,736' MD. 30% washout yields top of cement of about 9,850' MD. SFD washout15% T/ Sag River 10,871' MD. 30% washout yields top of cement of about 9,850' MD. SFD RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Wellhead: 1. PPPOT-T to 5000 psi (complete, passed on 8/25/24) 2. PPPOT-IC to 3500 psi (complete, passed on 8/25/24) Fullbore: 1. Pump Reservoir Abandonment plug, TOC is planned at ~10,200’ MD. Bullhead into the reservoir as follows: x 5 bbls MeOH x 10 bbls fresh water x 13 bbls 15.3 class G cement (3.8 bbls excess) x 2 bbls freshwater x Foam Ball x 198 bbls warm diesel displacement (75degF). x Max pressure 2650 psi Cement Type/weight:Class G 14-15.8 ppg Bottom hole temp:209°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours Cement Volumes: cap top btm vol size bpf MD'MD bbls 3-1/2"0.0087 10558 11000 3.8 4-1/2"0.0152 10200 10558 5.4 Excess ---3.8 Total ---13.0 Displacement: cap top btm vol size bpf MD'MD bbls 5-1/2"0.0232 0 5382 124.8 4-1/2”0.0152 5382 10200 73.2 Fullbore 1. WOC 3 days, MIT-T to 2500 psi target pressure–AOGCC Witnessed. Slickline 1. Drift and tag to TOC –AOGCC Witnessed. Eline: 1. Punch 4-1/2” tubing between ~10,100 – 10,200ft depending upon tag depth. Minimum TOC at 4-1/2" tubing tail at 10,794' MD. - mgr RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 A. Apply 1000 psi to 4-1/2” prior to punching, record before/after pressures. B. Circulate ~ 20bbls to verify punches are successful. Note any pressure changes. Fullbore: 1. Pump Abandonment plug, TOC is planned at ~3,200’ MD in tubing and IA. x 5 bbls MeOH x 10 bbls fresh water x 470 bbls 15.3 class G cement (3.8 bbls excess) x 2 bbls freshwater x Foam Ball x 74 bbls warm diesel displacement (75degF). x Max pressure 2650 psi Cement Type/weight:Class G 14-15.8 ppg Bottom hole temp:209°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours Cement Volumes: cap top btm vol size bpf MD'MD bbls 5-1/2"0.0232 3200 5382 50.6 4-1/2"0.0152 5382 10100 71.7 4-1/2” annulus 0.0535 5382 10100 252.4 5-1/2” annulus 0.0438 3200 5382 95.6 Total ---490 Displacement: cap top btm vol size bpf MD'MD bbls 5-1/2"0.0232 0 3200 74.2 A. Wait 3 days and pressure Test TxIA to 500 psi for 5 minutes. 2. Jet Cut 5.5” tubing @ ~3000’. Adjust depth to cut 2’ below a tubing collar. A. Use cutter rated for 5.5”, 17#, 13Cr tubing. RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Current Wellbore Schematic TOC 30% Washout - 9850' MD 4-1/2" Tubing Tail @ 10794' MD TSAG @ 10,871' MD RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Proposed Reservoir P&A with TBG cut, TBG punch, and cement detail included RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Tubing Tally RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Casing Tally RST Res P&A Sundry Well:01-12A PTD:202192 API:50-029-20269-01 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Operations Manager Date Operations Engineer Date Drilling Manager 09/28/23 Monty M Myers 323-537 By Grace Christianson at 10:32 am, Sep 29, 2023 DSR-9/29/23MGR03OCT23 * BOPE pressure test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement with a fully cemented liner on upcoming sidetrack. 10-407 SFD 10/4/2023*&:JLC 10/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.05 09:00:14 -08'00'10/05/23 RBDMS JSB 100523 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 28, 2023 Re: PBU 01-12A Sundry Request Sundry approval is requested to set a whipstock and mill the window in 01-12A, as part of the pre-rig, drilling and completing of the proposed 01-12B CTD lateral. Proposed plan for 01-12B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. Service coil will mill the 3-1/2" CIBP and push to bottom. E-line will set a 3-1/4" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See 01-12B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set the whipstock or mill window pre-rig, the rig will set the whipstock and/or mill a single string 2.74" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and land in Zone 2. The lateral will continue in Zone 2, 3 and back to 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing Ivishak perforations via the packer whipstock, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start October 2023): 1. Service Coil : Mill 3-1/2" CIBP a. Mill CIBP at 11,000' and push to bottom. 2. Slickline: Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 3. Fullbore: MIT a. MIT-IA and/or MIT-T to 2,500 psi 4. E-line: Set 3-1/4” packer whipstock a. Top of window at 11,112’ MD (top of whipstock = pinch point) b. Oriented 180° ROHS (Low Side) 5. Service Coil: Mill Window (mill with rig if needed) a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,415 psi IV. Mill 2.74” window plus 10’ of rat hole V. Single string window exit out of 3-1/4” liner 6. Valve Shop: Pre-CTD Tree Work as necessary Rig Work - (Estimated to start in December 2023): x Reference PBU 01-12B PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,415psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. RPM log and Perforate (only if not done post-rig) 6. Freeze Protect and RDMO 7. Set LTP* (if needed), RPM log and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) PTD 223-0XX Sundry 323-537 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 2.74” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x PBU DS-01 is an H2S pad. o The highest recorded H2S well on the pad was from 01-25 (900 ppm) in 2023. o The last recorded H2S on 01-12A is 14 ppm taken 2/7/2023. Reservoir Pressure: x The reservoir pressure is expected to be 3295 psi at 8,800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,415 psi (from estimated reservoir pressure). x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 323-537 SFD 10/4/2023 202-192 SFD 10/4/2023 PBU 01-12A By Samantha Carlisle at 8:21 am, Aug 02, 2022 MGR07SEP2022 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA . AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D o RECEIVI::.U JUN 2 0 2006 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P1 Stratigraphic 0 Stimulate D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 202-1920 o 6. API Number: 50-029-20269-01-00 9. Well Name and Number: Exploratory Service 73 ES 01-12A 8. Property Designation: ADL-028328 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth measured 12580 feet Plugs (measured) None true vertical 9144.67 feet :t~ ~Ured) None :~I!t,~~~f) . , .~ .~ß .",,.,~ Effective Depth measured 12548 feet true vertical 9116.59 feet Casing Length Size MD TVD Burst Conductor 80 20" 94# H-40 45 - 125 45 - 125 1530 Surface 2691 13-3/8" 72# N-80 43 - 2734 43 - 2734 5380 Production 11025 9-5/8" 47# N-80/RS-95 42 - 11067 42 - 8690.27 6870 Liner 483 3-1/2" 9.3# L-80 10558 - 11041 8359.15 - 8673.79 10160 Liner 98 3-3/16" 6.2# L-80 11041 - 11139 8673.79 - 8721.42 Liner 1441 2-7/8" 6.16# L-80 11139 - 12580 8721.42 - 9144.67 10570 Collapse 520 2670 4760 10530 11160 Perforation depth: Measured depth: 12125 - 12150 True Vertical depth: 8849.18 - 8860.71 12355 - 12365 8977.54 - 8983.26 12384 - 12428 8994.33 - 9022.33 Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# 13CR80 13CR80 21 - 5382 5382 - 10593 Packers and SSSV (type and measured depth) 4-1/2" TIW HBBP-T Packer 5-1/2" Baker SAB Packer 10537 10664 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFlJUN .~ 1 20D6 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P1 16. Well Status after proposed work: Oil P1 Gas 0 WAG Tubing pressure 166 o Service x Contact Sharmaine Vestal WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Revised 04/2004 Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 6/19/2006 Submit Original Only . . 01-12A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED I BBLS I 68 Netg . 160 . 1 % KCL 228 TOTAL I ACTIVITYDATE I SUI'!IIMt~Y 4/23/2006 CTU #4, Perf; MIRU unit. MU and RIH with PDS gamma ray / cel. Pump 30 bbl pill of 1 % KCL with safelube followed by 58 bbls of 60/40 meth. Log interval 11400'-12250' ctmd. Flag pipe at 12022' ctmd. POOH. MU and RIH with 25' of 2.0" HSD PJ2006 HMX, 6 spf. Correct to flag depth and perforate interval 12125'-12150' corrected ctmd. POOH; all shots fired. POOH. RDMO. *** Job Complete *** . . /3550 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Howard Okland 333 West 7th Avenue, Suite] 00 Anchorage, Alaska 99501 February 23,2004 RE: MWD Formation Evaluation Logs: 01-12A, AK-MW-22171 Ol-12A: Digital Log Images 50-029-20269-01 )D ~ - } ~ ~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~Date: 9-1~8IoL¡; Signed'~V n G - U ! . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marlœr.doc SChlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 1-311M-21 ,.:.) - CO'} J.. 07-34A ) IJC . ð~ J 15-14A :).ÛLt - .:ÀJ. ~ Y -23B ). 0 3 -. I ~ '"f N-08A J. \; ~- -t crt K-08A J.~-~ <.. J~~ W-26A I c\ c, - C ~ \ L5-09 , q D '" j).. i OWDW-NW í ~c· J... '1 ~ C-34 J 98· 6/ Y 01-12A ')" ~).. .. i qt DS05-41A)..tJ ~.- I~ 02-26C ). L~ S - () \ C\ Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051037 10980537 10831309 10928620 10715377 10928619 Log Description RST (REVISED)* RST (REVISED)* PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL *REVISED TO CORRECT API# ON DIGITAL DATA Date 04/14/05 04/26/05 01/16/05 06/09/05 09/24/04 06/24/05 06/23/05 04/27/05 03/26/05 07/09/04 04/03/05 01/21/04 03/20/05 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: :, \ ,~ / c}..;,Jt··, ~Î /V~~ \ SCf~NNEr- SEP O? 2005 07/14/05 NO. 3433 ~ O~- t c¡. ()- Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color CD 1 1 1 1 I -~ J _~ 3 I] Â ~ y i 1 )...) r· I J ìJ b' 1 1 1 1 1 1 1 1 1 1 J 313 7 /3 ),,18 iJ J.JCf J.} ).'-Il\ iJ4'-1¡ ;'))...41 .~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnCh~rage. AK 9~50732838 !: ATTN. Beth ; 1 ri {j Received by: ß-çl~\... ()J1J ~ tJ ;tö\\'Í DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Permit to Drill 2021920 Well Name/No. PRUDHOE BAY UNIT 01-12A MD 12580/' TVD 9145"r .,r><,r' Completion Date 10/31/2002/' REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RES, CNL, CCl Well Log Information: Log/ Data Digital Type jVled/Frmt l3PV :1og .~ e/C LY ~/, ~D Electr Dataset Number Name Directional Survey ~asing collar locator. vf4eutron ~41 Neutron US Verification ~mma Ray -<1'669 LIS Verification Well Cores/Samples Information: Name Interval Start Stop Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20269-01-00 Completion Status 1-01l Current Status 1-OIL UIC.J:'t." 0:--'...- Samples No Directional Survey ~YJ..A. , (data taken from logs Portion of Master Well Data Maint) Log Log Run Interval OH/ ~ Scale Media No Start Stop CH Received Comments 1 11000 12580 Open 11/12/2002 2 Blu 10175 12547 Case 217/2003 2 Blu 10175 12547 Case 217/2003 A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 9/18/2002. 10175 12547 Case 217/2003 10958 12537 Open 4/17/2003 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 9/18/2002. 2 Blu 10175 12547 Case 217/2003 .~ 10958 12537 Open 4/17/2003 Sample Set Sent Received Number Comments Permit to Drill 2021920 MD 12580 TVD 9145 ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? - Y ¡ N Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Well Name/No. PRUDHOE BAY UNIT 01-12A Operator BP EXPLORATION (ALASKA) INC Completion Date 10/31/2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? frJ¡ N @N Formation Tops k Date: API No. 50-029-20269-01-00 ~o :;;lCfÞ--~ Cl .~. ) J ó/o::J-/9;; / I (Ptt>9 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska March 31, 2003 RE: MWD Formation Evaluation Logs 01-12A, AK-MW-22171 1 LDWG formatted Disc with verification listing. API#: 50-029-20269-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: S@l4- ~()¿r0 RECe\VED APR 1 7 2003 Alaska Ot1 & Gas Cons. Commission Anchcng6 Scblumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well F-10A ~()O..Ç(o" D-30A ,..g,Orl ,ay h D.S. 1-12Ar-:i1~ -I q:J D.S.11-06 J lfJ- /0 I D.S.18-25A J't 7-0cr~ D.S.2-37 fq~ - L'7 5 L5-05 If- J- Oln CJ D.S.1-26A Color Date Blueline Sepia Prints CD 12/10/02 2 01/10/03 1 10/30/02 1 11/20/02 1 10/22/02 1 10/27/02 1 11/01/02 1 11/08/02 Job# Log Description 23002 SCMT 23030 LINER TOP TIE-IN MGRlCCL (PDC) 22513 MCNL 23019 RST-SIGMA 22487 MCNL 22511 MCNL 22512 RST-SIGMA 22509 RST-SIGMA (REPLACES BLANK CD) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECEIVED fEB 0 7 2003 AJaIka QI & Gas Cons. Commiseion Andmge 01/20/03 NO. 2821 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ -'~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received~ ~~ J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well r81 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 780' SNL, 755' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 174' SNL, 1274' EWL, SEC. 09, T10N, R15E, UM \jEr:~F:~ Cf} At total depth' ~'¥\ 119' SNL, 1135' EWL, SEC. 09, T10N, R15E, UM .,_._.~~...- 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 73' ADL 028328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 10-26-2002 ¡ 10-28-2002 ~ 10-31-2002 ~ 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12580 9145 FT 12548 9117 FT r81 Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,ROP,RES,CNL,CCL Classification of Service Well f...:.,..... ~.''''.ÓC..'. .Þ..1í(M.'.."......:j:..'..~...'. t~~' ~ 7. Permit Number 202-192 8. API Number 50- 029-20269-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 01-12A 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2188' MD 1900' (Approx.) 7;/P/(..-~ 1~t)Ç~ '~ð 8;? 9 3" '7(,/þ 23. CASING SIZE 20" 13-3/8" 9-518" WT. PER FT. 94# 72# 47# GRADE H-40 N-40 N-40 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 125' 30" 300 sx Arctic Set Surface 2734' 17-1/2" 5739 sx Permafrost II Surface 11060' 12-1/4" 765 sx Class IG', 300 sx Permafrost JTop Job) 200 sx Permafrost 12580' 3-3/4" 147 sx Class 'G' AMOUNT PULLED 3-1/2" x 3-3/16" 8.2# / 6.2# x 2-7/8" 16.16# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 SPF MD TVD L-80 10558' SIZE 5-1/2" x 4-1/2", 17# x 12.6#, 13Cr TUBING RECORD DEPTH SET (MD) 10593' 10593' - 10794' PACKER SET (MD) 10537' 10664' 25. MD TVD 5-1/2" x 4-1/2", 17# x 12.6#, N-80 12355' - 12365' 8978' - 8983' 12384' -12428' 8994' - 9023' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 16001 Freeze Protected with Methonal 27. Date First Production November 15, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. su~'~tt1 VI: U OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. RBDMS BFL NOV 2 7 201]2 NOV 2 2 2002 þþOU& Gas gems. Comm\sslan u ' Anchorage ./ ()y Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 45S8 11110' 8711' Top of Zone 3 12100' 8839' Top of Zone 2C 12208' 8891' Top of Zone 28 12351' 8975' Top of Zone 18 12535' 9106' RECEIVED NOV 2 2 2002 Alaska on & Gas Gons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the f/oin~ is true and correct to the best of my knowledge Signed Terrie Hubble /lO~ ~ Title Technical Assistant Date ll.;t ( .O^- 01-12A 202-192 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 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 (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) Page 1 of 8 BP EXPLORATION Operations Summary. RepQrt 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT Phase 10/22/2002 00:00 - 03:30 03:30 - 06:00 06:00 - 07:30 07:30 - 07:45 07:45 - 08: 15 10/23/2002 08:15 - 08:30 08:30 - 09:00 09:00 - 20:00 20:00 - 00:00 00:00 - 04:30 04:30 - 04:45 04:45 - 05:00 05:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 -17:15 17:15 - 18:45 18:45-21:30 21 :30 - 22:00 22:00 - 22:25 22:25 - 23: 15 23:15 - 23:45 23:45 - 00:00 10/24/2002 00:00 - 01: 15 01 :15 - 02:00 02:00 - 02:15 02:15 - 02:50 02:50 - 04:45 04:45 - 05: 15 05:15 - 05:40 3.50 MOB 2.50 MOB 1.50 MOB 0.25 MOB 0.50 MOB 0.25 MOB 0.50 MOB 11.00 MOB 4.00 RIGU 4.50 RIGU 0.25 MOB 0.25 MOB 3.00 MOB 3.00 RIGU P 1.00 BOPSURP 5.25 BOPSUR P 1.50 BOPSUR P 2.75 BOPSURN 0.50 STWHIP P 0.42 STWHIP P 0.83 STWHIP P 0.50 STWHIP P 0.25 STWHIP P 1.25 STWHIP P 0.75 STWHIP P 0.25 STWHIP P 0.58 STWHIP P 1.92 STWHIP P 0.50 STWHIP P 0.42 STWHIP P P P PRE PRE P PRE P PRE P PRE P P P P P P P PRE PRE PRE PRE PRE PRE PRE P PRE PRE DECOMP DECOMP DECOMP RREP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Description of Operations General RID & preparations to move rig. PJSM. Lower wind walls. Scope down & LID derrick in pipeshed. Move rig camp to DS#1. Move Gen #3. Warm up hydraulics for move. SAFETY MEETING. Review move rig off well procedure, hazards and mitigations. W.O. security, tool services & CPS for pre-move safety meeting. SAFETY MEETING. Reveiw route with security. Back off of well. Move to DS-1, Park in front of 01-12. PJSM. Raise derrick, raise windwalls. Continue RU PJSM Move rig over wellhead. Rig will not pass over wellhead. Too close. Call for rig mats. ACCEPT RIG AT 05:00 HRS, 10-23-2002. Position 6 rig mats in front of well. Back rig over tree and set down. General rig up of berms, tanks, hardline and positioning trailers. N/U BOPE. Perform initial BOPE Pressure I Function tests. BOPE test witnessed by AOGCC inspector, Lou Grimaldi. Load 300 bbls, 2% KCL water with 2 PPB Biozan in rig pits. Fill coil with 2# Biozan water, pump dart to check volume, dart bumped at 59.0 bbls. Press test BKR CT connector and CT inner reel valve. Actuator bonnet on BOP is leaking, need to replace. Function test, PT. PJSM prior to PU GR/CCL for tie-in. Discuss plan forward for night crew and the overall well plan. H2S is present on the pad, the last test on this well was zero PPM. MU ball drop disconnect so we can swap the well to 2ppb bio on the way out of hole. Originally had a burst disc in the MHA which only has one small hole to circulate thru. The circ sub has 4x 1/4" holes to circulate with. Bleed down WHP, take gas to outside bleed tank. IA=Opsi, OA=Opsi PU GR/CCL, Dowell MHA for tie-in. Stab injector. RIH with GR/CCL tie in assembly. RIH wI GR/CCL tie in assembly to 9000'. PU weight=38000Lbs. Log down at 58fpm from 9000'. IA= 165, OA=20 Tag bottom at 10965'. Drop 13/16" ball down to open circ sub. Displace 9-5/8" with 2ppb bio. PU and flag end of CT at 10860'. RBIH and tag bottom. Start logging up, 1.2bpm, 1000psi. Log up to 9000'. POH, displacing well with 2ppb bio. Never saw the ball hit. LD memory GR/CCL tool PU nozzle, stab injector and pump 13/16" ball off reel. Recovered ball. Printed: 11/4/2002 2:21:47 PM ) ) BP EXPLORATION Operations Summary Report Page 2 o.f 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Date Fro.m- To Ho.urs Task Code NPT Phase Description of Operatio.ns 10/24/2002 05:40 - 06:35 0.92 STWHIP P WEXIT PU 1.25deg Weatherford motor, 3.8" D331 GEB short parabolic mill, Sperry MWD, Sperry orientor, Dowell MHA, Baker CTC. 06:35 - 07:30 0.92 STWHIP P WEXIT RH with pilot hole assembly. SH test Sperry tools. Orienter failed, 1 click out of 6 cycles. 07:30 - 09:00 1.50 STWHIP N DFAL WEXIT POH, change out orienter. RIH to 3,000 ft and test orienter. OK. 09:00 - 10:30 1.50 STWHIP P WEXIT RIH with 3.80" Pilot milling BHA. Tagged Cement at 10,965 ft. Correct CTD to 10,944'. 10:30 - 10:45 0.25 STWHIP P WEXIT Orient TF to 165R 10:45 - 12:00 1.25 STWHIP P WEXIT Milling Hard cement, 2.7/2.7 bpm, 3550 psi, 165R TF. 20 FPH with 4K WOB. Milled to 10,970' 12:00 - 13:00 1.00 STWHIP P WEXIT Milling Hard cement, 2.5 I 2.5 bpm, 3250 psi, 165R TF. 20 FPH with 5K WOB. Milled to 10,990'. 13:00 - 14:30 1.50 STWHIP P WEXIT Milling Hard cement, 2.5/2.5 bpm, 3250 psi, 160R TF. 20 FPH with 6K WOB. Milled to 11,020'. 14:30 - 16:30 2.00 STWHIP P WEXIT Milling Hard cement, 2.5/2.5 bpm, 3250 psi, 165R TF. 20 FPH with 6K WOB. Milled to 11,048'. 16:30 - 17:00 0.50 STWHIP P WEXIT Orient TF to 15L. Back ream pilot hole to 10900'. Clean Pilot hole. Orient TF and ream down. 17:00 - 18:30 1.50 STWHIP P WEXIT Mill Cement ramp at 18L TF. Start ramp at 11,048 ft. 2.7 / 2.7 bpm, 3300 psi, 5K WOB. Milled hard cement to 11060 ft at 18L TF. Back ream Pilot hole up to 10,930 ft. Dress top of pilot hole at 10944' at 6L TF. Flag CT at 10,800' EOP [10,865.1' bit depth]. 18:30 - 20:15 1.75 STWHIP P WEXIT POH for Window Milling BHA. PJSM on LD pilot assembly and PU window milling assembly. 20: 15 - 20:45 0.50 STWHIP P WEXIT LD pilot hole assembly, BHA #3. 20:45 - 21 :45 1.00 STWHIP P WEXIT PU Window milling assembly w/ DP0088 speed mill, Weatherford 3deg motor, Sperry orientor/MWD, 13/16" Dowell Disconnect, 2jts PH6, 15/16" Dowell Disconnect, Dowell MHA, Baker CTC. 21 :45 - 00:00 2.25 STWHIP P WEXIT RIH with Window milling assembly 10/25/2002 00:00 - 00: 1 0 0.17 STWHIP P WEXIT Correct depth, neg. 24.5' to EOP Flag at 10,800'. RIH to 10957.5' and orient TF to 50L. 00:10 - 00:20 0.17 STWHIP P WEXIT Shut down pumps, RIH at 37fpm. RIH wt=20000. Tag bottom at 11059.97'. PU to 11048'. RBIH, bring pumps on, TF=44R. Need TF close to highside. Shut down pumps, PU 10931' and start over. 00:20 - 00:45 0.42 STWHIP P WEXIT Orient to 90L. RIH at 35fpm, get one click, TF= 45R on bottom.PU, orient on ramp at 11051.8'. RIHTagat11060', PU 3' to 11057', Orient to TF of 3L. Good TF to start milling. 00:45 - 00:55 0.17 STWHIP P WEXIT Tag bottom and FLAG PIPE AT 11058'md. PU 1', to 11057'. Free spin= 3580psi RIH wt.= 170001bs. 00:55 - 01:40 0.75 STWHIP P WEXIT Start time milling sequence. 11057', 2.8/2.8/3660, TF=3L 01:40-02:16 0.60 STWHIP P WEXIT 11057.1 2.8/2.8/3640 TF=9R, Stringwt.=26000 02: 16 - 02:46 0.50 STWHIP P WEXIT 11057.2 2.8/2.8/3610 TF=9R, String wt. = 23750 02:46 - 03: 13 0.45 STWHIP P WEXIT 11057.3 2.8/2.8/3620 TF=9R, String wt. = 21848 03:13 - 03:38 0.42 STWHIP P WEXIT 11057.4 2.8/2.8/3640 TF=9R, String wt = 20650 03:38 - 04:02 0.40 STWHIP P WEXIT 11057.5 2.8/2.8/3640 TF=9R, String wt = 19740 04:02 - 04:25 0.38 STWHIP P WEXIT 11057.6 2.8/2.8/3700 TF=9R, String wt = 18960 04:25 - 04:47 0.37 STWHIP P WEXIT 11057.7 2.8/2.8/3740 TF=9R, String wt = 17400 04:47 - 05:08 0.35 STWHIP P WEXIT 11057.8 2.8/2.8/3780 TF=9R, String wt = 16000 Printed: 11/4/2002 2:21:47 PM ) ) BP EXPLORATION Operations ..Summary.. Report Page 3 efa Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Date From-To Hours Task Code NPT Phase Descriptienof Operations 1 0/25/2002 05:08 - 05:28 0.33 STWHIP P WEXIT 11057.9 2.8/2.8/3800 TF=9R, String wt = 16300 05:28 - 06:01 0.55 STWHIP P WEXIT 11058.0 2.8/2.81 3760 TF=9R, String wt= 16223 06:01 - 06:28 0.45 STWHIP P WEXIT 11058.1 2.9/2.9/3900 TF=9R, String wt=15600, TF is steady not seeing any reactive. 06:28 - 06:51 0.38 STWHIP P WEXIT 11058.2 2.8/2.8/3660 TF=9R, String wt= 16500 106:51 - 08:00 1.15 STWHIP P WEXIT 11058.3 2.8/2.8/3660 TF=9R, String wt= 15300, Taking WOB. 08:00 - 09:00 1.00 STWHIP P WEXIT 11058.7', 2.8/2.8/3700, TF = 9R, WT = 15K 09:00 - 10:00 1.00 STWHIP P WEXIT 11059.2', 2.8/2.8/3730, TF = 9R, WT = 15K 10:00 - 11 :00 1.00 STWHIP P WEXIT 11059.7', 2.8/2.8/3900, TF = 9R, WT = 14.6K 11 :00 - 12:00 1.00 STWHIP P WEXIT 11060.5', 2.8/2.8/4020, TF = 9R, WT = 14.1K, Still taking wt and drilling off. Looks good so far. 12:00 - 13:00 1.00 STWHIP P WEXIT 11061.5', 2.8/2.8/4070, TF = 3R, WT = 14K, End time drilling schedule and Mill with 4K WOB. 13:00 - 13:30 0.50 STWHIP P WEXIT 11063.0', 2.8/2.8/4100, TF = 20L, WT = 12.2K, Stacking more I wt. See reactive TF to left. 13:30 - 14:00 0.50 STWHIP P WEXIT 11064.0', 2.8/2.8/4120, TF = 20L, WT = 12.2K, steady milling with 4K WOB. 14:00 - 14:30 0.50 STWHIP P WEXIT 11,066'. Exit 9-5/8" Casing at 11065.3'. Note all window milling depths listed need to be corrected [ + 2.0 ft], to put on depth with tied-in previous pilot hole depth of 11,060 ft. Top of Window at 11,060 ft, Bottom of window at 11,067 ft. 14:30-16:15 1.75 STWHIP P WEXIT Mill formation from 11067 - 11074 ft. [corrected depth]. 15 FPH, 2.7 I 2.7 bpm, 4550 psi. 3L TF. Circ. 30 bbl very high viscosity Biozan pill while drilling formation to lift metal cuttings from window milling. Pull up thru window with minimum pump to top of cement at 10,944'. Chase sweep to surface. 2.9 bpm, 4100 psi. Did get extra metal over shaker with sweep. Flagged CT at 10,800' EOP. 16:15 - 18:15 2.00 STWHIP P WEXIT POH with 3 deg motor. 18:15 -18:30 0.25 STWHIP P WEXIT SAFETY MEETING. Review BHA C/O and cutting coil procedures, hazards and mitigation. 18:30 - 20:30 2.00 STWHIP P WEXIT UO mill, motor, hyd disc and 2 jts PH6. CIO Sperry Equalizer jet to 13/32". Cut off 100 ft of CT. M/U Baker CTC. Pull/ Press test CTC. M/U 3.78" Taper Mill, 2.25 deg WF Motor, MWD, orienter and MHA. BHA = 66.4 ft. 20:30 - 22:20 1.83 STWHIP P WEXIT RIH with 2.25 deg WF motor, etc.. Depth correct to EOP flag at 10696'md (adjusted from 10800' after cutting 104' of CT) Neg 24.3' correction. RH to 1 0925'md 22:20 - 22:45 0.42 STWHIP P WEXIT ORIENT TF to 82L. RIH pumping min rate. 0.3/0.3/1370 RIH wt=19500. Set down at top of window. PU, 10000K overpull. PU to 11052.5, Orient to 56L. Sit down again at 11 060'md. PU to 11051.3, Orient to 35L. 22:45 - 00:00 1.25 STWHIP P WEXIT Ream down thru the window at 1.2fpm. TF between 30L-18L. Work past tight spot at top of window. Continue, hang up at bottom of the window. Park at BOW with zero WOB, TF=18L. Repeated stalls. PU on the stalls and ease back down to bottom of window. 10/26/2002 00:00 - 02:55 2.92 STWHIP P WEXIT RIH to 11071.7 at 18L. Backream up thru window at 0.3fpm, 18L. RIH without pumps, tag at 11070. Backream up thru the Printed: 11/4/2002 2:21:47 PM ') ) BP EXPLORATION Operations Summary Report Page 4 of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N 1 Spud Date: 11/5/1977 End: 10/31/2002 Date From.;. To HoUrs Task Code NPT Phase Descri ptionof Operätions 1 0/26/2002 00:00 - 02:55 2.92 STWHIP P WEXIT window at OTF. RBIH at 17R 2.3/2.3/3000. Pump high vis pill around. Still seeing motor work rih at bottom of window, we are able to drift past this spot with pumps off. Backream up past top of window at 17R. [IA=290, OA=145psi] RBIH to 11070 with pumps on, stall on bottom. Back ream up thru the window. Send FloPro down hole. Run through window with pumps off, tag at 11069.1. Swap hole to flo-pro. 02:55 - 04:35 1.67 STWHIP P WEXIT POH, FLAG PIPE at 10,700'md (End of pipe). White flag. 04:35 - 04:45 0.17 STWHIP P WEXIT SAFETY MEETING on LD/PU tools. Watch pinch points and body positioning. Discuss BHA to PU. 04:45 - 05:30 0.75 STWHIP P WEXIT UO mill, motor. M/U 3.75" Used M09, 2 deg Baker HP Motor, Sperry MWD, Sperry orienter, Dowell MHA and Baker CTC. BHA =65.5 ft. 05:30 - 07:30 2.00 DRILL P PROD1 RIH with build assembly, BHA #5, Shallow hole test orientor. Good test. RIH. Correct depth at flag at 10,700' EOP. [-27 ft CTD] 07:30 - 07:40 0.17 DRILL P PROD1 Orient TF to 20L. 07:40 - 08:00 0.33 DRILL P PROD1 RIH thru window to 11070' with min. pump. Tag TO at 11072', corrected depth to 11,074'. 08:00 - 08: 1 0 0.17 DRILL P PROD1 Drilling Build Section, 2.6/2.6 bpm, 3360 - 4100 psi, Drilled to 11,078'. TF shifted. 08:10 - 08:20 0.17 DRILL P PROD1 Orient TF to 20L 08:20 - 09:20 1.00 DRILL P PROD1 Drilling Build Section, 2.6 1 2.6 bpm, 3360 - 4100 psi, TF = 20L, 60 FPH, Drilled to 11,130' 09:20 - 11 :00 1.67 DRILL P PROD1 Drilling Build Section, 2.6 1 2.6 bpm, 3360 - 4100 psi, TF = 30L, 50 FPH, Drilled to 11,196'. 11 :00 - 11 :50 0.83 DRILL P PROD1 Drilling Build Section, 2.6/2.6 bpm, 3360 - 4100 psi, TF = 40L, 50 FPH, Drilled to 11,220' 11 :50 - 12:30 0.67 DRILL P PROD1 Orient TF to 95L 12:30 - 12:45 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 12:45 - 13:30 0.75 DRILL P PROD1 Drilling Turn Section, 2.6 1 2.6 bpm, 3360 - 4000 psi, TF = 95L, 80 FPH, Drilled to 11,260'. 13:30 - 14:00 0.50 DRILL P PROD1 Drilling Turn Section, 2.6/2.6 bpm, 3360 - 4000 psi, TF = 95L, 80 FPH, Drilled to 11,281'. 14:00 - 14:40 0.67 DRILL P PROD1 Orient TF to 120L. 14:40 - 15:40 1.00 DRILL P PROD1 Drilling Turn Section, 2.6/2.6 bpm, 3360 - 4000 psi, TF = 120L, 80 FPH, Drilled to 11,353' 15:40 - 16:30 0.83 DRILL P PROD1 Drilling Turn Section, 2.6/2.6 bpm, 3400 - 4000 psi, TF = 120L, 80 FPH, Drilled to 11,400'. 16:30 - 17:00 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 17:00 - 18:00 1.00 DRILL P PROD1 Drilling Turn Section, 2.6/2.6 bpm, 3400 - 4000 psi, TF = 130L, 80 FPH, Drilled to 11,455'. 18:00 - 19:30 1.50 DRILL P PROD1 Drilling Turn Section, 2.61 2.6 bpm, 3400 - 4000 psi, TF = 110L, 90 FPH, Drilled to 11,526'. 19:30 - 19:55 0.42 DRILL P PROD1 Wiper to window. Clean hole. 19:55 - 20:35 0.67 DRILL P PROD1 Orient to 120L. Difficult getting clicks. 20:35 - 22:00 1.42 DRILL P PROD1 Drilling Turn Section, 2.6 I 2.6 bpm, 3400 - 4000 psi, TF = 120L, 90 FPH, Drilled to 11,630'. Completed build section. 22:00 - 00:00 2.00 DRILL P PROD1 POH with build assembly 10/27/2002 00:00 - 00:10 0.17 DRILL P PROD1 Continue POH with build assembly 00:10 - 00:15 0.08 DRILL P PROD1 SAFETY MEETING: Discuss BHA changeout and safety awareness. 00:15 - 01 :15 1.00 DRILL P PROD1 LD 2deg motor, M09 bit, and MWD. PU 1.37deg HP motor, Printed: 11/4/2002 2:21 :47 PM ') ) BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Date From- To Hours Task Code NPT Phase Description of Operations 10/27/2002 00:15 - 01:15 1.00 DRILL P PROD1 used DS49. 01:15-02:15 1.00 DRILL P PROD1 RIH with Lat BHA, BHA #6, 1.37deg motor, Bit #5, used DS49 srl# 103231. Daylight Savings Time Change 02:15 - 02:35 0.33 DRILL P PROD1 Tie in pulling up below window. Subtract 22' CTD. 02:35 - 02:50 0.25 DRILL P PROD1 RIH, Orient to 117L. 02:50 - 04:00 1.17 DRILL P PROD1 Drilling Lateral section, 2.7/2.7 bpm, 3600 - 3900 psi, TF = 117L, 90 FPH, Drilled to 11,721' Freespin=3420 04:00 - 05:00 1.00 DRILL P PROD1 2.7/2.7 bpm, 3600 - 3900 psi, TF = 100L, 90 FPH, Drilled to 11,785' 05:00 - 05:25 0.42 DRILL P PROD1 Wiper back to window 05:25 - 06:15 0.83 DRILL P PROD1 2.7/2.7 bpm, 3600 - 4050 psi, TF = 100L, 90 FPH, Drilled to 11,839' 06:15 - 06:30 0.25 DRILL P PROD1 Orient to 90R 06:30 - 08:00 1.50 DRILL P PROD1 Drilling Lateral, 2.6 12.6 bpm, 3500 - 4000 psi, TF = 90R, 100 fph, Drilled to 11,950'. 08:00 - 09:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 09:00 - 09:30 0.50 DRILL P PROD1 Drilling Lateral, 2.6 I 2.6 bpm, 3500 - 4000 psi, TF = 11 OR, 100 fph, Drilled to 12,000'. 09:30 - 09:45 0.25 DRILL P PROD1 Orient to 135L. 09:45 - 10:30 0.75 DRILL P PROD1 Drilling Lateral, 2.6 1 2.6 bpm, 3500 - 4000 psi, TF = 135L, 100 fph, Drilled to 12,056'. 10:30 - 10:45 0.25 DRILL P PROD1 Orient to 175L 10:45 - 11:45 1.00 DRILL P PROD1 Drilling Lateral, 2.5 1 2.5 bpm, 3350 - 4000 psi, TF = 175L, 80 fph, Drilled to 12,097'. 4 stalls at 12,097'. 11:45 -13:00 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH, lost wt at 11,860', back reamed and RIH. 13:00 - 13:30 0.50 DRILL P PROD1 Orient TF to 160R 13:30 - 14:10 0.67 DRILL P PROD1 Drilling, several stalls, Top of Zone 3 from ROP = 12,097'. 2.6/2.6 bpm, 3280 - 3900 psi, TF = 160R, Swap to new FloPro while drilling ahead. Drilled to 12,112'. 14:10 - 16:10 2.00 DRILL P PROD1 Drilling Latera', 2.5/2.5 bpm, 3100 - 4000 psi, TF = 165R, 10 fph, Drilled Zone 3 to 12129'. Bit is shot, MWD signal intermittent 16:10 -16:55 0.75 DRILL P PROD1 Wiper to window. Overpulls at 11800-900'. Flag at 10800' EOP 16:55 - 18:30 1.58 DRILL P PROD1 POOH for bit 18:30 - 18:45 0.25 DRILL P PROD1 SAFETY MEETING: Discuss PUlLD tools, continue to monitor OAlIA pressures, DS-1 is an H2S pad. Good use of STOP program. 18:45 - 20:45 2.00 DRILL P PROD1 LD Sperry MWD, DS49. PU Used M09, new Sperry MWD package. Cut 100' of CT 20:45 - 23:25 2.67 DRILL P PROD1 RIH, shallow hole test Sperry tools, good test. 23:25 - 00:00 0.58 DRILL P PROD1 Drilling,2.6/2.6bpm 2800-3200psi, TF 93R, Drilled to 12150'. Out of Z3 at 12140' based on ROP 10/28/2002 00:00 - 00: 15 0.25 DRILL P PROD1 Drilling,2.7/2.7bpm 2900-3400psi, TF 93R, Drilled to 12161'. 00: 15 - 00:30 0.25 DRILL P PROD1 Orient to 176L, start dropping. 00:30 - 02:20 1.83 DRILL P PROD1 Drilling,2.7/2.7bpm 3000-3600psi, TF 176L-150L, Drilled to 12295' 02:20 - 03:00 0.67 DRILL P PROD1 Wiper trip to window, get one click on bottom. 03:00 - 03:46 0.77 DRILL P PROD1 Drilling,2.7/2.7bpm 2800-4000psi, TF 126L-100L, Drilled to Printed: 11/4/2002 2:21:47 PM ') ') BP EXPLORATION Operations Summary Report Page.6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/28/2002 03:00 - 03:46 0.77 DRILL P PROD1 12333' 03:46 - 04:00 0.23 DRILL P PROD1 Orient 130L 04:00 - 05:00 1.00 DRILL P PROD1 Drilling,2.7/2.7bpm 3200-3700psi, TF 130L, Drilled to 12376'. 60fpm. ROP is slowing to 25-30fpm. Likely entering shale at top of Zone 2b. 05:00 - 06:05 1.08 DRILL P PROD1 Drilling,2.7/2.7bpm 3200-3300psi, TF 103L, Drilled to 12385'. Stacking wt., ROP inconsistent. Freespin=31 00. Clean Pick-up. RIH wt is smooth. Believe the bit is worn out. 06:05 - 06:50 0.75 DRILL P PROD1 POH for new bit and Resistivity sub. 06:50 - 07:30 0.67 DRILL P PROD1 Log tie-in up from 11110', corr -3.0'. Flag CT @ 10800' EOP 07:30 - 09:10 1.67 DRILL P PROD1 POOH for bit 09:10 -10:55 1.75 DRILL P PROD1 Change bit. Add Resistivty, upload 10:55 - 13:05 2.17 DRILL P PROD1 RIH w/ BHA #8. Work on e-counter 20 min. Corr -19' at flag 13:05 - 14:25 1.33 DRILL P PROD1 Precautionary ream to TD 2.6/3140 14:25- 14:40 0.25 DRILL P PROD1 Tag TD at 12380'. Orient to low side 14:40 - 16:50 2.17 DRILL P PROD1 Drilling from 12380' 2.6/3250/174R in and out of shales, dropping angle as planned. Drill to 12530' 16:50 - 17:45 0.92 DRILL P PROD1 Wiper to window while CBU looking for HOT in samples. Overpull at 11900' 17:45 - 18:00 0.25 DRILL P PROD1 Log tie-in up from 11120', add 5.0' 18:00 - 18:40 0.67 DRILL P PROD1 RIH to TD, hole in good condition. 18:40 - 18:50 0.17 DRILL P PROD1 Tag TD, PU and Orient to 179L. 18:50 - 20:10 1.33 DRILL P PROD1 Freespin=3390. Drilling 2.7/2.7bpm 3500-3700psi. Dropping angle. Resistivity Dropping off. Call TD at 12580'md. 20: 1 0 - 22:30 2.33 DRILL P PROD1 Mad Pass up 11fpm. 22:30 - 00:00 1.50 DRILL P PROD1 POH 10/29/2002 00:00- 00:30 0.50 DRILL P PROD1 POH 00:30 - 01 :00 0.50 DRILL P PROD1 Stand back injector start downloading resistivity data. 01 :00 - 01 :30 0.50 DRILL P PROD1 SAFETY MEETING while downloading resistivity data. Discuss LD tools and PU liner. 01 :30 - 02:30 1.00 DRILL P PROD1 LD Drilling BHA, Resistivity tool. 02:30 - 06:50 4.33 CASE P COMP PU 2-7/8" x 3-3/16" x 3-1/2" solid liner. Liner includes short joint, millable XO and X profile below deployment sleeve. MU CTLRT 06:50 - 07:40 0.83 CASE P COMP Install Baker CTC. PT 3700 psi, 35K 07:40 - 09:20 1.67 CASE P COMP RIH wI liner on 2-3/8" CT 09:20 - 09:45 0.42 CASE P COMP See flag 39' deep at 10970' CTD-did not correct. 41.6k, 21 k. RIH thru window to TD at 12614' CTD, clean. Recip 40' at 51k, retag at 12613' (solid). Corr to 12580' (TOL @ 10558') 09:45 - 10:45 1.00 CASE P COMP Circ 10 bbls 1.0 bpm @ 2000 psi 1/1. Load 5/8" steel ball. Displace wI mud 2.0/2770, 0.6/1750. Ball seat sheared at 4020 psi. Confirm released from liner, then pump 1.0/1940 10:45 - 12:45 2.00 CASE P COMP Displace mud with 2% KCI 2.5/2.5 @ 3350 start, 2.4/2.2 @ 2400 end 12:45 - 13:00 0.25 CEMT P COMP Safety mtg re: cement 13:00 - 13:25 0.42 CEMT P COMP Batch up cement 1.0/0.8 @ 430 13:25 - 14:05 0.67 CEMT P COMP PT DS @ 3500 psi. Load CT w/ 30 bbls 'G' cement at 16.0 ppg 2.0/1.82300. Load/launch wiper dart and check 14:05 - 14:40 0.58 CEMT P COMP Displace cement with 2% KCI2.5/2.2 1400. Saw CT press incr when cement exited shoe and continued to increase while displacing liner (which is normal). CT wiper did not latch liner wiper plug. Under displace by 0.8 bbl to leave calc TOC at 12400'. Returns past shoe were 27.2 bbls. Chk floats and Printed: 11/4/2002 2:21:47 PM ') ) BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From- To Hours Task Code NPT Phase 1 0/29/2002 14:05 - 14:40 0.58 CEMT P COMP 14:40 - 16:55 2.25 CASE P COMP 16:55 -17:15 0.33 CASE P COMP 17:15 -17:30 0.25 CASE P COMP 17:30 - 18:30 1.00 CASE N SFAL COMP 18:30 - 19:00 0.50 CASE N SFAL COMP 19:00 -19:15 0.25 CLEAN N SFAL COMP 19:15 - 19:30 0.25 CLEAN N SFAL COMP 19:30 - 21:45 2.25 CLEAN N SFAL COMP 21:45 - 23:10 1.42 CLEAN N SFAL COMP 23:10 - 00:00 0.83 CLEAN N SFAL COMP 10/30/2002 00:00 - 00:30 0.50 CLEAN N SFAL COMP 00:30 - 01 :00 0.50 CLEAN N SFAL COMP 01 :00 - 02:40 1.67 CLEAN N SFAL COMP 02:40 - 03:00 0.33 CLEAN N SFAL COMP 03:00 - 04:30 1.50 CLEAN N SFAL COMP 04:30 - 04:45 0.25 EVAL P COMP 04:45 - 05:15 0.50 EVAL P COMP 05:15 - 05:45 0.50 EVAL P COMP 05:45 - 06:00 0.25 EVAL P COMP 06:00 - 07:00 1.00 EVAL P COMP 07:00 - 08:25 1.42 EVAL P COMP 08:25 - 10:00 1.58 EVAL P COMP 10:00 - 11 :20 1.33 EVAL P COMP 11 :20 - 13:30 2.17 EVAL P COMP 13:30 - 13:45 0.25 EVAL P COMP 13:45 -14:45 1.00 EVAL P COMP 14:45 - 15:00 0.25 EVAL P COMP 15:00-15:15 0.25 EVAL P COMP 15:15-16:00 0.75 EVAL P COMP 16:00 - 16:30 0.50 EVAL P COMP Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N 1 Spud Date: 11/5/1977 End: 10/31/2002 Description of Operations held. Unsting from TOL at 34k. Jet TOL at 2.0 bpm 1/1 POOH jetting excess cement OOH. Dumped 62 bbls cement contaminated KCI wI density up to 12.9 ppg. Est recovered 8 to 13 bbls cement LD CTLRT and liner wiper plug was still attached. BOT breakdown LRT and check for dart, none found RIH with side jet nozzle. Jet stack. Open up dart launching valve & poke thru with a 3' rod stick - no sign of dart. Break-off 10" long x 3" 10 45deg elbow & recovered dart in it. The 8.5" long dart with 2" 00 fins was corked inside the elbow. Elbow was installed because CT inlet is close to the reel btm & needs to be angled-up to connect the inner reel valve & other hardline. Unstab injector & UD side jet nozzle. Safety mtg re: CSH workstring RU to run CSH MU 2.3" 0331 DSM, 2-1/8" motor, MHA. PU 66 CSH singles RIH w/ BHA #9 10600' 35.5k Start motor 1.5/2000, RIH precautionary reaming 25'/min. Cmt comp str 1000 psi Continue precautionary ream from 12000' 1.5/2250 25'/min, clean. Motor work from 12564' to stall at 12574' CTD (Latch collar placed at 12547' ELMO by tally so normal correction for this well). Confirm with another tag and stall at 12574'-this is latch collar. PUH 41.8k Backream 2-7/8" liner 1.4/197041 k POOH w/ CT Safety mtg re: standback CSH. Drop ball, open circ sub Standback workstring. LD mill, motor Safety mtg re: source PU CNL tools to floor and load source MU CSH doubles Crew change/safety mtg Fin MU CSH doubles. Kick drill. RIH with CT synchronizing depths with SWS. Pump down 15bbls perf pill @ 0.5bpm & 250psi. RIH to 10200'. Log down from 10200' @ 30fpm. Tag PBD at 12572' CTD. Log up from 12572' to 10200' @ 30fpm while leaving 15 bbls fresh high LSRV perf pill in liner. POOH from 10200'. PJSM for SIB CSH. Standback 33 stands of 1-1/4" CSH. PJSM for UD logging tools. UD MCNUCCUGR tools. Install tree cap. Line up to test liner lap. Fill hole with 3.5 bbls of KCL. Compressive strength of cement - 3000psi. IAJOA @ 0/155 psi @ onset of test. Staged up in 500 psi intervals, monitoring I/A. PT @ 2038 psi, leaked 53 psi in 30 mins, no change in IAJOA pressure thoughout test. Review forward plan with town & decide to go ahead with perforating. AOGCC Rep, John Spaulding granted 24 hrs waiver on BOP testing. Download MCNUCCUGR data and faxed to town geologist. Logged PBTD @ 12548' & TOL @ 10559'. Printed: 11/4/2002 2:21:47 PM ) ) Page 8 of8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Datë 10/30/2002 10/31/2002 01-12 01-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From- To Hours Task Code NPT Phase 16:30 - 18:15 1.75 EVAL P COMP 18:15 - 18:30 0.25 EVAL P COMP 18:30 - 20:00 1.50 EVAL P COMP 20:00 - 20: 15 0.25 PERF P COMP 20:15 - 20:30 0.25 PERF P COMP 20:30 - 20:50 0.33 PERF P COMP 20:50 - 22:00 1.17 PERF P COMP 22:00 - 00:00 2.00 PERF P CaMP 00:00 - 00:50 0.83 PERF P COMP 00:50 - 02:45 1.92 PERF P COMP 02:45 - 03:00 0.25 PERF P COMP 03:00 - 04:30 1.50 PERF P COMP 04:30 - 04:45 0.25 PERF P COMP 04:45 - 05:15 0.50 PERF P CaMP 05:15 - 05:30 0.25 RIGD P COMP 05:30 - 06:45 1.25 RIGD P COMP 06:45 - 07:15 0.50 RIGD P COMP 07:15 - 09:00 1.75 RIGD P COMP Start: 10/23/2002 Rig Release: 10/31/2002 Rig Number: N1 Spud Date: 11/5/1977 End: 10/31/2002 Description of Operations W.O. the confirmation of perf intervals. Geo calls back with modified perf intervals of 12355' - 12365' & 12384' - 12428'. SWS runs back to go reload guns. DS inspect and grease injector Load perf guns in pipeshed Safety mtg re: perf guns MU 4 SWS 2" HSD 4 spf PJ guns w/firing head MU 33 stands workstring RIH wI BHA #11 Tag PBD at 12573.3' and corr to 12548'. PUH 47k to ball drop point. Pump 7 bbls fresh mud. Load 5/8" steel ball. Position guns. Displace wI 7 bbls fresh mud then 2% KCI. Ball seat sheared at 2900 psi. Perforated 12355-365', 12384-428' wI 2" HSD PJ guns at 4 spf POOH 45k. No fluid lost while POOH Safety mtg re: standback CSH Standback workstring Safety mtg re: perf guns LD perf guns-all shots fired. Load out guns Blow down hardline to flowback tank wI air RU nozzle assy. RIH pumping MeOH. POOH freeze protecting wellbore from 1600'. SI swab with 36 turns. CIO packoff. Unstab & SIB injector. Meanwhile clean out pits & tanks. PJSM for ND. Nipple down BOP. Will N/U & PIT tree cap after rig is moved off well due to height clearance. Rig Released at 09:00 Hrs on 10/31/2002. Total Time for 01-12A: 9.38 days. Operations Time = 8.17 days. Printed: 11/4/2002 2:21:47 PM ) ') AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1-12A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 11,000.00 I MD Window / Kickoff Survey 11,056.00' MD (if applicable) Projected Survey: 12,580.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED William T. Allen Survey Manager NOV 12 2002 AlasKa œ & Gas Cons. Commillion AnchOflge Attachment(s) dOd-} 9:2 04-Nov-02 Sperry-Sun /:J1'iIfIffg Services North PBU_, 01 III Job No. AKMfIV22121, ort 8 Novtl1þbflJ;,11f2 Your.f, :''''''''''letlØ1 Surface Coordinates: 5940126.51 H, 6. .," 1~E'/(7(Jo 14'25.9320. H, 148024' 00.6554" W) Grid Coordinate System: NAtJ27 Alaska sr.te Planes, Zone 4 Surface Coordinates relative to ProJectHReffitence: 940126.51 IJ; 198088.31 E (Grid) Surface Coordinates relative to Strucfure Rtference: 1826.20 S, 800.51 E(True) Kelly Bushing: 73.ØØh abøVeMean Sea Level Elevation relative to PtOJectV Reference: 73.0Oft Elevation relative to StructUré Relel'ènce : 73.00ft ~ ...... .."'\'~"'n .., bFflLLI~U8.'. ~.PVl,".. A H.tflburton company ')EFNTVE .-. ~ Survey Ref: svy11356 Sperry-Su" SutVey Report for Your R~," Job No. A ->''f.-~-;/' >" -'-.-. ' ., BPXA North Slope Alaska -, Measured Sub-Sea Vertical Local Coordlì..~", - ,.".,', Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northh1gs ¡_tlnOI Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11000.00 49.500 110.000 8574.22 8647.22 190.09 S &tea..e, 5940080.64 N 703577.27 E 1606.29 Tie-on Point - 11056.00 49.780 110.000 8610.49 8683.49 ... 204.68 S 6526.9I'S', 5940067.10 N 703617.74 E 0.500 1605.55 Window Point 11088.20 62.110 107.400 8628.48 8701.48 213.17 S 5551.19èE 5940059.27 N 703643.18 E 38.867 1605.73 11123.75 68.720 104.500 8643.27 8716.27 222.03 S 5582.26E 5940051.23 N 703674.47 E 20.016 1607.47 11156.75 75.240 101.800 8653.47 8726.47 229.15 S 5612.80 E 5940044.92 N 703705.19 E 21.232 1610.68 ''-- - 11184.92 81.460 99.530 8659.16 8732.16 234.25 S 5639.90 E 5940040.53 N 703732.41 E 23.447 1614.68 11218.83 87.140 94.560 8662.53 8735.53 238.38 S 5673.36E 5940037.29 N 703765.98 E 22,205 1621.68 11253.67 88.810 88.220 8663.76 8736.76 239.22 S 5708. 15',E 5940037.36 N 703800.77 E 18.807 1632.20 11284.15 89.070 82.580 8664.33 8737.33 236.78 S 5738.51 E 5940040.60 N 703831.06 E 18.520 1644.40 11323.45 85.370 77.110 8666.23 8739.23 229.86 S 5777.13 E 5940048.52 N 703869.49 E 16.788 1663.51 11356.92 85.290 69.360 8668.96 8741.96 220.25 S 5809.05E 5940058.97 N 703901.14 E 23.079 1682.99 11392.22 85.900 61.960 8671.68 8744.68 205.75 S 5841.()fE 5940074.31 N 703932.79 E 20.972 1707.13 11426.97 85.200 54.030 8674.38 8747.38 187.41 S 5810.48E 5940093.42 N 703961.66 E 22.840 1734.04 11457.75 84.050 47.860 8677.26 8750.26 168.11 S 5894.23 E 5940113.33 N 703984.93 E 20.304 1760.02 11491.13 84.760 40.460 8680.52 8753.52 144.29 S 5917.36 E 5940137.75 N 704007.42 E 22.165 1790.07 11523.70 86.960 33.770 8682.88 8755.88 118.40 S 593t3.9&-E 5940164.15 N 704026.32 E 21.570 1820.93 11555.92 85.640 27.250 8684.96 8757.96 90.72 S 5t5:t21-E 5940192.25 N 704041.90 E 20.605 1852.42 11586.58 84.410 19.140 8687.62 8760.62 62.67 S 5965.29E 5940220.61 N 704053.18 E 26.655 1882.85 11630.80 85.460 9.980 8691.53 8764.53 20.08 S 5976.34E 5940263.47 N 704063.12 E 20.769 1926.72 11661.25 84.320 5.220 8694.25 8767.25 9.97N 5980.36E 5940293.62 N 704066.34 E 16.014 1956.44 11691.82 83.960 0.290 8697.37 8770.37 40.34 N 5981.82E 5940324.01 N 704067.00 E 16.086 1985.63 11729.72 83.260 354.470 8701.59 8774.59 77.95 N 5980.10 E 5940361.56 N 704064.29 E 15.372 2020.63 11763.32 83.170 348.130 8705.57 8778.57 110.91 N 5975.05 E 5940394.38 N 704058.39 E 18.739 2050.15 -,~ 11794.97 84.490 343.190 8708.97 8781.97 141.38 N 5967.26.& 5940424.64 N 704049.80 E 16.068 2076.43 11826.70 85.990 337.730 8711.60 8784.60 171.17 N 5956.69 E 5940454.14.~ 704038.44 E 17.787 2101.15 11858.20 84.320 338.440 8714.26 8787.26 200.29 N 5944.97 E 5940482.94 N 704025.97 E 5.758 2124.87 11898.00 82.200 344.250 8718.94 8791.94 237.72 N 5932.33 E 5940520.02 N 704012.35 E 15.444 2156.15 11938.42 82.910 350.070 8724.18 8797.18 276.78 N 5923.43 E 5940558.84 N 704002.42 E 14.385 2190.18 11973.47 79.030 352.000 8729.68 8802.68 310.96 N 5918.04 E 5940592.87 N 703996.13 E 12.333 2220.74 12007.55 76.480 355.880 8736.91 8809.91 344.07 N 5914.51 E 5940625.87 N 703991.74 E 13.407 2250.90 8 November, 2002 - 8:28 Page 2014 DrlllQuest 3.03.02.002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12044.27 73.390 350.590 8746.46 8819.46 12082.63 68.550 345.130 8758.97 8831.97 12112.67 64.930 350.240 8770.84 8843.84 12146.05 61.760 343.720 8785.83 8858.83 12177.50 58.940 340.370 8801.39 8874.39 12212.38 53.660 335.790 8820.74 8893.74 12252.65 53.040 324.690 8844.83 8917.83 12282.80 53.300 317.470 8862.92 8935.92 12318.95 55.330 310.590 8884.02 8957.02 12352.95 55.420 301.780 8903.36 8976.36 12383.38 54.010 294.910 8920.95 8993.95 12418.21 48.550 293.500 8942.73 9015.73 12451.66 43.080 289.270 8966.04 9039.04 12489.06 37.620 288.570 8994.54 9067.54 12520.86 33.480 286.450 9020.40 9093.40 12552.06 28.630 286.450 9047.12 9120.12 12580.00 28.630 286.450 9071.65 9144.65 Sperry-SuI1¡if)L: . Survey Report for PlìU- Your Rtf::: . Job NO. ' ,,' Sarvices .0,...01-12 - 1-12A . f.'- '"21, ".~il~ ," Local CoordiØåti$-. Northingsl!áítl .,' (ft) (ftJ;7~'I OlObalCoordinates NêJtthlngs Eastlngs (ft) (ft) 379.26 N 5910.3$fE 5940660.94 N 703986.66 E 414.70 N 5902¡7'ê,ê 5940696.16 N 703978.13 E 441.64 N 5896..'S 5940122.94 N 703971.53 E 470.68 N 5890.ile 5940151.80 N 703964.07 E 496.68 N 5881.15E 5940777.57 N 703954.98 E 523.59 N 5870..e 5940804.19 N 703943.49 E 551.57 N 58M..e 5940831.74 N 703926.77 E 570.32 N 5839:83E 5940850.08 N 703911.14E 590.69 N 5818.1áe 5940869.89 N 703889.51 E 607.18 N 5196.18-e 5940885.78 N 703866.54 E 618.98 N 5774.35E 5940897.00 N 703844.40 E 630.13N 5149.58E 5940907.49 N 703819.35 E 638.90 N 5727.28e 5940915.68 N 703796.82 E 646.76 N 5104.38 E 5940922.93 N 703773.73 E 652.34 N 5686.16 E 5940928.05 N 703755.97 E 656.89 N 5611.33E 5940932.20 N 703740.42 E 660.68 N 5658..,E 5940935.65 N 703727.49 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to Ttue Nôfcth. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Ref~ce . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 19.000° (True). Magnetic Declination at Surface is 26. 189°(22-0ct-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12580.0Oft., The Bottom Hole Displacement is 5696.93ft., in the Direction of 83.340° (True). 8 November, 2002 - 8:28 Page 30'4 BPXA Dogleg Vertical Rate Section Comment (°/1 OOft) 16.256 2282.82 18.442 2313.85 19.731 2337.41 19.868 2362.69 12.886 2384.53 18.662 2406.47 22.155 2427.72 19.182 2440.52 16.442 2452.91 21.317 2461.16 18.998 2465.20 15.990 2467.68 18.692 2468.71 14.649 2468.69 13.582 2468.23 15.545 2467.51 0.000 2466.91 Projected Survey '-'" DrillQuest 3.03.02.002 North Slope Alaska Comments Measured Depth (ft) . "-.. 11000.00 11056.00 12580.00 Sperry-Sun ". -wices Survey Report for PIfU- . --,.- 1.01.12. 1.12A YourRM: ~1 Job No~ .AK_f21, Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 8647.22 8683.49 9144.65 190.09 S 204.68 S 660.68 N 5485.86 E 5525.96 E 5658.49 E Survey taallJraQram far 01-12 - 1-12A From Measured Vertical Depth Depth (ft) (ft) 0.00 ~. 8 November, 2002 - 8:28 Comment Tie-on Point Window Point Projected Survey To Measured Vertical Depth Depth Survey Tool Descrlptlön (ft) (ft) 0.00 12580.00 9144.65 MWD Magnetic(1-12A) BPXA -.-./ ---- Pagè4of4 DrillQlIest 3.03.02.002 penmts tor WeUs K.-1bA ðl; 1-12 Subject: Permits for Wells K-16A & 1-12 Date: Mon, 16 Sep 2002 13:58:29 -0500 From: "Sherwood, Alistair" <SherwooA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Winton, In Prudhoe last week we ran into some difficulty with soft roads & moving Nordic 1 out to R pad. This forced us to change around the drilling schedule. The dates for both K-16a & 1-12 have been been brought forward as a result. If there is any chance of getting the Drilling Permit, (10-401) for K-16a L 1 & L2 and the Drilling & Sundry Permit, (10,403) for 1-12asome time this week, that would be greatly appreciated. Regards Alistair Sherwood Coil Tubing Drilling Engìneer Greater Prudhoe Bay BP Exploration (Alaska) 900 E. Benson Blvd. Anchorage. +(907) 564 4378 +(907) 440 8301 ) ~ 1f !A\ IE (ill Œ\ L0j ) ATASIiA ORAND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 01-12A BP Exploration (Alaska), Inc. Permit No: 202-192 Surface Location: 780' SNL, 755' EWL, Sec. 08, T10N, R15E, UM Bottomhole Location: 147' SNL, 1241' EWL, Sec. 09, T10N, R15E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. . The permit to redrill does not exempt you from obtaining (additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter .25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ÚJ1\A~ ðlJv:k - ~~L, Cammy OOchsli Tayl~; ð -- . Chair BY ORDER OF. THE COMMISSION DATED this~ day of September, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 780' SNL, 755' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 980' SNL, 984' EWL, SEC. 09, T10N, R15E, UM At total depth 147' SNL, 1241' EWL, SEC. 09, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ,,/ ADL 028329, 1241' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11040' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 3-3/4" 3-1/2" x 3-3116" 8.2# / 6.2# L-80 STL x 2-7/8" /6.16# ALASKA ~l AND ~~;~g~S~':;~ON COMMk)ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool RKB = 73' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028328 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /.,' /lit., 01-12)1 9. Approximate spud date" 11/01/02 /" Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12450' MD / 9020' TVDss 0 17. Anticipated pressure {~20 AAC 25.035 (e) (2)} 88 Maximum surface 2280 psig, At total depth (TVD) 8800' /3287 psig Setting Depth TOD Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 1750' 10700' 8378' 12450' 9020' 113 sx Class 'G' r \IJ Ck q {/¿léJ Î- ~ 9/ltl7.ðÞ2- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12001 feet 9296 feet 11512 feet 8978 feet Length Plugs (measured) Set Sand Plug at 11512 (05/11/00) Junk (measured) Yes, see attached diagram. Size Cemented MD TVD 125' 2734' 20" 13-3/8" 300 sx Arcticset 5739 sx Permafrost II 125' 2734' 125' 2734' 11982' 9-5/8" 765 sx Class 'G', 300 sx PF Top Job: 200 sx PF 9284' Perforation depth: measured 20. Attachments Open: 11454' - 11464', 11465' - 11478', 11479' - 11509' ;, ¡.~;V'", fin ;.ž; i.~,;.¡ Sqzd or Below Sand Plug: 11424' -11454', 11524' - 11554', 11570' -11g1Si;S.n~9~';'~'116i1i"i~\W~~i"Je641" 11641' - 11646' Open: 8940' - 8947', 8947' - 8956', 8957' - 8976' " ,. Sqzd or Below Sand Plug: 8921' - 8940', 8986' - 9006', 9016' - 9020', 9032' - 9039', 9053' - 9063', 9063' - 9066' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21.~:~:~y C;a:~::::h71j~ ~át&°~:::E2=~i~~~ Date 9/5/02 Permit Number API Number A.RP'rov¡;.1 Date See cover letter Zc:;~ -/,92- 50- 029-20269-01 L11 J1 ¡I)'.a for other reauirements Conditions of Approval: Samples Required 0 Yes ŒI No Mud Log Required 0 Yes 1211 No Hydrogen Sulfide Measures ¡¡J Yes 0 No Directional Survey Required a Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Test ßoPE fo-ssoo p~¿ . On9,nal Signed B) by order of Approved By Cammy Oechsli Taylo? üK-. .." ..,."S,iG.' r~ f\. , jtthrommission Form 10-401 Rev. 12-01-85 ) t-\ ~ ~ ~ ~\!¡ J!J ì '\ I .)J I I \ij ¡ \ true vertical Date CJ¡ .r¡j~ Submit In Triplicate ) ) BP 1-12a CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for 1-12. The coil sidetrack, 1-12a, will exit the 9 5/8" casing in the Ivishak Zone 4 formation and target Zone 2. Phase 1: Prep work. Planned for Sep-Oct. / 1. Dummy off all GLM's and perform IA MIT to 2500 psi 2. Service coil to mill X nipples, cement sheath in ~ing to 3.80" 3. Service coil to downsqueeze and lay in -50bbl17ppg cement for cement ramp kick off. Phase 2: Mill window, Drill and Complete sidetrack: Planned for November 1, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Mud Program: . Phase 1: Seawater /' . Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: / . The production liner will be 3-1/2 ST-L x 3 3/16" TC II x 2 7/8" ST-L from TD to approx. 10,700'MD (-8378'TVDSS). . Liner cement volume will a minimum of 23 bbls. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional , . See attached directional plan. Max. planned hole angle is 88 deg. ( . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray, Resistivity will be run over all of the open hole section. Memory CNL will be run inside the liner. Hazards / . 1-12 has no H2S. Max recorded H2S on DS 1 is 140ppm (1-07A). . No fault crossings expected, however risk of lost circulation is high if a subseismic fault is encountered. . Possible stuck pipe in highly permeable Zone 3. Reservoir Pressure Res. press. is estimated to be 3287.4 psi at 8800'ss (7.18 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2280 psi. TREE = GRAY WELLI-EAD = GRAY AcwÁfÔ¡:f;".MAXELSÖN .KS:.ËLï3/, ;;."..~M",,~u~u"~""73Î ï3F:1~LEV..;;...... ,,,,,,.<o,u~~..~.,..,......,,,..,,.. ~'''''<~..".,.,......"...,...,.""...~m'..,.,..... . KOP= ""","""'.~"<O""~."".'~"'''''' Max Angle = 51 @ 9800' Datum IVD == 11351' 6atümi\T5^;-'~m." äé6ëF'ss ') 13-3I8"CSG, 72#,N-80,ID=12.34T' H 2734' 15-1/2"TBG, 17#, 13-CR, .0232 bpf, ID =4.892" H 5382' ITOPOF4-1/2"TBG H 5382' Minimum ID = 3.725" @ 10573' 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID =3.958" l-i 10593' I TOP OF 5-1/2" lBG-NFC 1-1 10593' 1 15-1/2" TBG-NFC, 17#, N-80, .0232 bpf, ID = 4.892" - 10676' TOPOF 4-1/2" lBG-NPC - 10676' 14-1/2" TBG-NOC, 12.6#, N-80, .0152 bpf, ID = 3.958" l-i 10794' PERFORATION SUIVMARY REF LOG: BHCS ON 11/25/77 ANGLEA TTOP ÆRF: 50 @ 11032' t\bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 3-1/8" 4 11424-11454 S 03101/91 3-3/8" 4 11454 - 11464 0 09/26/96 3-3/8" 6 11465 - 11478 0 12/01/96 3~3/8" 6 11479 - 11499 0 09/24/96 4 11499-11509 0 03109/91 3-1/8" 4 11524-11554 S 03101/91 3-1/8" 4 11570 - 11575 S 05/11/01 §}1 11512' 9-5/8" CSG, 47#, N-80/RS-95, ID = 8.681" H 11982' ~ 12001' 01-12 8 ~ l \ ! -----. L ::8: ~ !~ z z ~ \ I I \ I ... , DATE REV BY COtv'MENTS DATE REV BY COMWENTS 12/04/77 ORGINAL COfvPLETION 06105/02 KB/KA K PERF CORRECTONS 02/02/96 LAST WORKOVER 03/08/01 SI8- M) 03/20/01 RI'flP CORRECTIONS 04/14/02 lLH DRAWNG CORRECTONS 05/09/02 CMO/KK MAX ANGLE CORRECTION ) SAFETY NOTES: WAIVEREDWB..L - T x IA COMM UNICA TION DLRIOO SQZ 02/11/00. LlM IT ED IA x OA COMMUNICATION TO AIL. 2188' H 5-1/2" f-ES HRQ SSSV NP, ID = 4.562" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV lYÆ VLV LATŒi PORT DATE 1 3475 3465 18 LB RA 5382' H 5-1/2" X 4-1/2" XO, NSCTI GAS LIFT MANDRB..S TVD DEV TYÆ VLV LATCH PORT DATE 5465 47 TB RA 6740 47 TB RA 7648 48 TB RA 8253 51 TB RA ST MD 2 6231 3 8114 4 9437 5 10390 1 10537 H 10573' H 10594' H 10626' H 1 10664' H 1 10676' H 9-5/8" X 4-1/2" TIW HBBP-T A<R 1 4-1/2" I-ES XN NIP, ID = 3.725" I 4-1/2" X5-1/2"XO 1 BAKERSBRBBL W/NOSEALS 1 9-5/8" X 5-1/2" BAKER SAB A<R 1 5-1/2" X4-1/2"XO 1 I 10735' H 4-1/2"BAKERRLANDlNGNIP,ID=3.759" 1 1 10794' H 4-1/2" TUBING TAL I 1 10782' H B..MDTTLOGGED I 11500' - PNFROMRALATŒi1-1/2"X1/2" & ALLEN SCREW (LOST 08122/96) 11506' ~ TT FINGER 4-1/2" X 1/2" LONG & SPRING (LOST 02/14/96) PRLOf-OE BA Y !.NIT WELL: 01-12 PERMrr No: 1770580 AR No: 50-029-20269-00 SEC 9 T1 ON R15E 3596.68 FB.. 1217.24 FNL BP Exploration (Alaska) .TRæ= , GRAY WELLHEAD= GRAY .ÄcfuÄTÖR;"""W"MÄXELSOÑ 'KB:~ELËV~;mmmmm_~w,~wW^'~já' -" "'W"'^''''^'.'.'.'.'''''.W...',''''''''W~'''...W.'W.WMW.,.."",w'',.....m,^WM"',w^".="""'^ BF. ELEV = ..W".W.W.W.W.v.r,',",',',""""",',Vuw,""''''','.'.',",','....."<'.y.-.w.,.,.--.w","'...w.wü",,,,,,,,,,,,,,,,,,,,,,',.,.,..w.w.w.. KOP= w.....'''''...............'.w.......w.....'.'.'.w.-.w...w...w.w.....................v.'.'~~.-..........w.'.............w.....'.....w.....'.""W"" Max Angle = "í5âtLìm"MD;w,^wm._.,..m~_mm11"35F -""""''^'.w,.,,,,,,,,,,,"U,='''''''''''''.........w.......w..~.............ww.......--''''W~W.'"""""""''''''''''''''''''''''''...",,............. Datum lVD= 8800' SS 01-12A Proposed CTD Sidetrack. 13-3/8" CSG, 72#, N-80, ID = 12.347" 1--1 2734' 5-1/2" TBG, 17#, 13CR, .0232 bpf, ID = 4.892" - 5382' TOPOF 4-1/2" TBG - 5382' Minimum ID = 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" - 10593' TOPOF 5-1/2" TBG-NPC - 10593' 5-1/2" TBG-NPC, 17#, N-80, .0232 bpf, ID = 4.892" - 10676' ITOPOF 4-1/2" TBG-NPC - 10676' 1 4-1/2" TBG-NPC, 12.6#, N80, .0152 bpf, ID = 3.958" 1--1 10794' I ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/25/77 ANGLE AT TOP ÆRF:- 50 @ 11032' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 11424 - 11464 isolated proposed 3-3/8' 4 11454 - 11464 isolated proposed 3-3/8' 6 11465 - 11478 isolated proposed 3-3/8" 6 11479 - 11499 isolated proposed 3-1/8" 4 11479 - 11509 isolated proposed 4 11479 - 11509 isolated proposed 3-1/8" 4 11524 - 11554 isolated proposed 3-3/8" 4 11534 - 11554 isolated proposed 3-1/8" 4 11570 - 11575 isolated proposed IPBTDI--1 11512' I 9-5/8" CSG, 47#, N-80/RS-95, ID = 8.681" 1--1 11982' DATE REVBY COMMENTS 12/04/77 ORIGINAL COMPLETION 02/02/96 LAST WORKOVER 03/08/01 SIS- MD 03/20/01 RNITP CORRECTIONS 04/14/02 TLH DRA WING CORRECTIONS ~ / L \--1" ...b g ~ I I ( ) :8: :8: ~ L.)SAFETY NOTES: WAIVEREDWB.L. / T x IA communication during squeeze 2/11/00.Limited IA x OA Communication to AIL. 2188' l---i 5-1/2" HES HRQ SSSV NIPPLE, ID = 4.562" I GAS LIFT MANDR8.S ST MD lVD DEV 1YÆ VLV LATCH PORT DATE 1 3475 3465 18 LB RA ST MD 2 6231 3 8114 4 9437 5 10390 GAS LIFT MANDR8.S lVD DEV 1YÆ VLV LATCH 5465 47 TB RA 6740 47 TB RA 7648 48 TB RA 8253 51 TB RA PORT DA TE '...;,.:,.:::.... L I 10537' l---i 9-5/8" X 4-1/2" TIW HBBP-T PACKER I I 10573' 1---1 4-1/2" HES XN NIPPLE, MILLED TOI I !D =: 3.80" 10626' - BAKER SBR BBL WINO SEALS 1 10664' - 9-5/8" X 5-1/2" BAKER SAB PACKER I I 10700' 1-1 Top of 3-3/16" Liner I 10735' 1---14-1/2" BAKER R LNDG NIP, 110= 3.80" M!LLED TO I /. 1 109401 1-1 Top of Cement 1-13-3/16 x 2-7/8 X-over c:::::J 0 I 3-3/16" X 2-7/8" cmt'ed and perfedl-i 12450' I 11040' 1-1 Cement Ramp Window 1 11500' I- I 115061 1- DA TE REV BY COMMENTS 05/09/02 CMO/KK MAX ANGLE CORRECTION 09/08/02 MSE PROPOSED CTD SIDETRACK ~--1 12001' I PIN FROM RA LATCH 1-1/2" X 1/2" & ALLEN SCREW (LOST 08/22/96) TT FINGER 4-1/2" X 1/2" LONG & SPRING (LOST 02/14/96) PRUDHOE BAY UNIT W8.L: 01-12A PERMIT No: API No: 50-029-20269-01 SEC9 T10N R15E3596.68 F8. 1217.24 FNL BP Exploration (Alaska) BP Amoco LEGEND - 01-01A (01-01A) 01-12(01-12) - Plan#201-12A - Plan #2 T ^M ¿ Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 Plan: Plan #2 (01-12IPlan#2 01-12A) Created By: Brij Potnis Date: 71212002 Azimuths to True North Magnetic North: 26.30. Stre~~~~~~~~~~ Dip Angle: 80.81. Date: 7/2/2002 Model: BGGM2oo2 Contact Information: P.....}=~t: ilia' It.,. O.ttlntl MLLPATH D8TAlL8 P/O.1n 01-12<1 500252021801 01.12 11040.00 Nordic 1 20 .1211/8/1877 00180 73.00ft v.s..:.::.: o.~ ~:I!= 18.00' 0.00 0.00 :=~ 0.00 1100 ---- REFERENCE INFORMATION r:-,:,-~'-:lI",t", (N'E1 1'>"""""'"""'" Well Centre: 01-12, True North '1 ':' :,';' ,',~ s: ~~: ;:~~:.:~ ~Yo~~rj 'to~N:g~~)el Measureo Oepm lielerence: 20: 12 111511977 00:00 73.00 Calculation Method: Minimum Curvature 8.C'nON D8TAlLa 110 Inc All +11" DL.. TFac. vs.c Tarset .. 11000.00 ",10 110.00 80'40 -180.08 88 0.00 0.00 1808.30 ! Hm:;i ::= ~i!~ Sit.n :55 =:5 51s ¡;:!¡ 8 114U.00",87 H.?f "".17 .112.72 2400 281.00 1788.32 8 1tMJ.GO 17.11 311.70 .....,. 220.08 88'8.71 12.00 271.00 21"'.0 7 12141.00 18.41 311..' 8'n.81 .'.18 "88.08 12.00 208.00 2S80.21 . 11480.00 28.81 183.37 lOaeM 83430 8712.70 12.00 210.00 24'.". ANNOTATION' TYD MD Aaoota- ..7U2 11_.00 TIP 8801.15 11040.00 KOP ..10.37 11057.00 1 8..1.84 11182.78 2 '''8.17 11oSa.OO 3 "".38 11N3.00 . 5782.87 121.0.00 . 8820," 12-.00 TD TARGET DETAILS 1\1) +NJ.s +EJ.W Shape g1:1~frr.1 wJ~ m:~ ml~ ~~ 8250...; 8300...: 8400 - C 8450 - ~ 850t} J 81) ::: 1 - .c 8550- ... t8600 ~ a - ëi 865t}:- U :e 8700 : e > 8750 e ë 8800 f- 885t} 8900 895t} ~; II -I 1 9000-/' '-'¡- -, 1 1 1 1 1 II 1450 1500 7/2/2002 3:03 PM ~ '-.-P ) ) . ii¡~Tätlh---~-'- BP Baker Hughes INTEQ Planning Report ~BPAmoço pr~Clt:lO&:I3ê¡ty P8DS01. . .01.;12 . Rtap#2:Q1~12A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level p:nnpautY: Fiêld: Sitè: . Well: WellP~th: Field: PB DS 01 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 01-12 01-12 Well Position: Well: ~~:)1121~pQ2 ~. . 1'im~f'.1S:Ò~:33. r.: .'.~~~r4~~t~)'.J!~~r~~~{" '.. Vf~~~'Öf~1~1'~~.Nortt(. . .¥~~~(',f~~:~~f~~~~; . §y~!~n;F.M~~;§~~.'~~ve.I.. .... S~i~il~~l~ef~l!çe: ....'. . .yv~tlQ,OO~;~.O()E.t9.QQ~i) .'O...'.".a;";~e".' .~ttiyey.Ç.JJIjt~Q.Meth~:. Minimum.etuv~wre . Db: . \.it 1 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5941932.14 ft 697237.60 ft Latitude: Longitude: North Reference: Grid Convergence: 70 14 43.905 N 148 24 24.004 W True 1.50 deg Slot Name: 12 70 14 25.943 N 148 24 0.637 W +N/-S -1826.31 ft Northing: 5940127.59 ft +E/-W 803.83 ft Easting : 698088.91 ft Position Uncertainty: 0.00 ft Latitude: Longitude: WeUpath: Plan#2 01-12A 500292026901 Current Datum: 20: 1211/5/197700:00 Magnetic Data: 7/2/2002 Field Strength: 57542 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Description. . Dip. Dil". 01-12A Polygon2.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 01-12A T2.1 -Plan hit target 01-12A T2.2 -Plan hit target TV» n. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8878.00 9020.00 Annotation MD TVD ft ft 11000.00 8574.22 TIP 11040.00 8600.15 KOP 11057.00 8610.37 1 11192.78 8651.54 2 11443.00 8669.17 3 11843.00 8699.39 4 12143.00 8792.87 5 12450.00 9020.04 TD Height 73.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 01-12 11040.00 ft Mean Sea Level 26.30 deg 80.81 deg Direction deg 19.00 +N/-S ft 0.00 ~p.' . M~p. '..;:~.LåtitUd~..~~ ~7:to~de +E/..W . Nofthi.g .'E~~g . Dêg '1\t~;Seç .J)eg"l\filt' 'Seç ;ft ft. ft 854.27 5726.84 5941131.99 703791.00 70 14 34.323 N 148 21 14.146 W 854.27 5726.84 5941131.99 703791.00 70 14 34.323 N 148 21 14.146 W 267.80 5469.33 5940538.99 703549.01 70 14 28.557 N 148 21 21.645 W -162.36 5545.06 5940110.99 703636.01 70 14 24.326 N 148 21 19.453 W -384.62 6122.45 5939903.99 704219.01 70 14 22.135 N 148 21 2.674 W 245.94 6301.09 5940538.99 704381.01 70 14 28.335 N 148 20 57.466 W 825.40 6140.25 5941114.00 704205.01 70 14 34.036 N 148 21 2.128 W 571.15 5841.44 5940851.99 703913.00 70 14 31.537 N 148 21 10.821 W 634.23 5763.07 5940912.99 703833.00 70 14 32.159 N 148 21 13.098 W ) BP ) ...8 .... Baker Hughes INTEQ Planning Report lÑTEQ ---_._-. ç()IttP~ny: BP AmoGe> J)~:7121'looi,. . ... .' J'im~;,;.t§;)3;33, . " . . "ag~: . ~. Field: PiudhoéJ3ay (;~~~~(t~~~).~ø~~~~,~~,: . ,~~;,.Q~r;1~,:,~f . Nort~ Site:. PBDSOt . -. .y~~:~)J~êf!r~I!~:'.' '...~~t~~;M~~. .h~Vêr..' ..,. WeD: Ot~12 .'~~~,,'O'S)~~fe~l!ç~.: '.." '. '. '~eJF«)'99f'1J;~~.. .~~,QO~U... Wellpáth: P~n#2'01.;12A ~~ey'Ç(tIÇ~I.~o"~~(Ji . MinifJ)Um'CÜrvatufè. . .'. Dbi Ol'aClê' Plan: Plan #2 Date Composed: 71212002 Identical to Lamar's Plan #2 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 'M» IOd. AZim TVD +Nl~ .+EÄ\V' DI;S' Build' TurD' . TEO . 'l'arg~t . ft cJ~, deg ft >ft ft' dfJ9Il~;'d~$(1'900d,~1q~ d~ .. : 11000.00 49.50 110.00 8574.22 -190.08 5485.86 0.00 0.00 0.00 0.00 11040.00 49.70 110.00 8600.15 -200.50 5514.48 0.50 0.50 0.00 360.00 11057.00 56.29 107.89 8610.37 -204.89 5527.32 40.00 38.75 -12.42 345.00 11192.78 88.00 99.87 8651.54 -234.68 5651.27 24.00 23.36 -5.90 345.00 11443.00 84.67 39.77 8669.17 -152.72 5875.00 24.00 -1.33 -24.02 265.00 11843.00 87.18 351.70 8699.39 220.08 5979.73 12.00 0.63 -12.02 271.00 12143.00 56.41 331.69 8792.87 487.18 5896.08 12.00 -10.26 -6.67 209.00 12450.00 28.91 293.37 9020.04 634;30 5762.70 12.00 -8.95 -12.48 210.00 Survey MD . Iud AZiin . SSTvn NIS . EðV :~pN' . MåPJt VS . DLS 'rFO Tool. ft deg ø~. ft ft: it ft " :,'ft ft .øe9ltQOft . dt1l9. .. 11000.00 49.50 110.00 8574.22 -190.08 5485.86 5940081.73 703577.56 1606.30 0.00 0.00 TIP 11025.00 49.63 110.00 8590.44 -196.59 5503.74 5940075.69 703595.61 1605.96 0.50 0.00 MWD 11040.00 49.70 110.00 8600.15 -200.50 5514.48 5940072.07 703606.45 1605.76 0.50 360.00 KOP 11050.00 53.57 108.71 8606.35 -203.10 5521.88 5940069.66 703613.91 1605.72 40.00 345.00 MWD 11057.00 56.29 107.89 8610.37 -204.89 5527.32 5940068.01 703619.40 1605.79 /40.00 345.80 1 11075.00 60.47 106.60 8619.81 -209.43 5541.96 5940063.86 703634.15 1606.26 24.00 345.00 MWD 11100.00 66.29 104.99 8631.01 -215.51 5563.45 5940058.35 703655.79 1607.52 24.00 345.67 MWD 11125.00 72.13 103.51 8639.88 -221.25 5586.10 5940053.20 703678.58 1609.46 24.00 346.40 MWD 11150.00 77.98 102.12 8646.32 -226.60 5609.64 5940048.48 703702.25 1612.07 24.00 346.93 MWD 11175.00 83.83 100.79 8650.27 -231.50 5633.82 5940044.21 703726.56 1615.31 24.00 347.28 MWD 11192.78 88.00 99.87 8651.54 -234.68 5651.27 5940041.49 703744.07 1617.98 24.00 347.49 2 11200.00 87.85 98.14 8651.80 -235.81 5658.39 5940040.55 703751.23 1619.23 24.00 265.00 MWD 11225.00 87.35 92.16 8652.85 -238.05 5683.26 5940038.96 703776.14 1625.21 24.00 265.06 MWD 11250.00 86.87 86.17 8654.11 -237.69 5708.21 5940039.98 703801.08 1633.67 24.00 265.31 MWD 11275.00 86.43 80.18 8655.57 -234.72 5732.98 5940043.60 703825.76 1644.54 24.00 265.62 MWD 11300.00 86.03 74.18 8657.22 -229.19 5757.29 5940049.77 703849.92 1657.69 24.00 265.97 MWD 11325.00 85.67 68.17 8659.03 -221.15 5780.88 5940058.43 703873.29 1672.97 24.00 266.36 MWD 11350.00 85.36 62.16 8660.98 -210.68 5803.49 5940069.48 703895.61 1690.23 24.00 266.80 MWD 11375.00 85.10 56.15 8663.07 -197.92 5824.87 5940082.80 703916.65 1709.26 24.00 267.27 MWD 11400.00 84.89 50.13 8665.25 -182.98 5844.79 5940098.25 703936.16 1729.86 24.00 267.77 MWD 11425.00 84.74 44.10 8667.51 -166.05 5863.02 5940115.66 703953.94 1751.81 24.00 268.29 MWD 11443.00 84.67 39.77 8669.17 -152.72 5875.00 5940129.30 703965.56 1768.32 24.00 268.84 3 11450.00 84.69 38.92 8669.82 -147.33 5879.42 5940134.81 703969.84 1774.85 12.00 271.00 MWD 11475.00 84.75 35.91 8672.12 -127.56 5894.54 5940154.96 703984.44 1798.47 12.00 271.08 MWD 11500.00 84.83 32.90 8674.39 -107.02 5908.61 5940175.86 703997.96 1822.47 12.00 271.36 MWD 11525.00 84.92 29.89 8676.63 -85.77 5921.58 5940197.45 704010.36 1846.78 12.00 271.63 MWD 11550.00 85.03 26.88 8678.82 -63.86 5933.41 5940219.66 704021.62 1871.35 12.00 271.90 MWD 11575.00 85.15 23.87 8680.96 -41.36 5944.08 5940242.43 704031.70 1896.10 12.00 272.16 MWD 11600.00 85.28 20.86 8683.05 -18.32 5953.56 5940265.71 704040.57 1920.97 12.00 272.42 MWD 11625.00 85.43 17.86 8685.08 5.19 5961.82 5940289.42 704048.20 1945.88 12.00 272.67 MWD 11650.00 85.58 14.85 8687.04 29.10 5968.84 5940313.51 704054.59 1970.78 12.00 272.91 MWD 11675.00 85.75 11.85 8688.92 53.35 5974.59 5940337.90 704059.71 1995.58 12.00 273.15 MWD 11700.00 85.94 8.84 8690.74 77.88 5979.07 5940362.54 704063.54 2020.23 12.00 273.38 MWD 11725.00 86.13 5.84 8692.46 102.61 5982.26 5940387.34 704066.07 2044.65 12.00 273.59 MWD 11750.00 86.33 2.84 8694.11 127.48 5984.15 5940412.25 704067.31 2068.78 12.00 273.80 MWD 11775.00 86.55 359.85 8695.66 152.42 5984.73 5940437.20 704067.24 2092.56 12.00 274.00 MWD 11800.00 86.77 356.85 8697.12 177 .37 5984.01 5940462.12 704065.86 2115.91 12.00 274.19 MWD 11825.00 87.00 353.85 8698.47 202.24 5981.99 5940486.93 704063.19 2138.77 12.00 274.36 MWD 11843.00 87.18 351.70 8699.39 220.08 5979.73 5940504.70 704060.46 2154.90 12.00 274.52 4 ) ') / BP Baker Hughes INTEQ Planning Report ç~,*PaJJY:. BP Aítíoêo Fi~ld: . PrlJçJh~~y site; PRDS (},1 .. Wèll: ()1...12 Wênp~tIt: Plan#2.Q142A Survey . MD Ind AZUri SS'fV]), ft ,~,~ -~~g ft . 11850.00 86.44 351.29 8699.78 11875.00 83.82 349.83 8701.90 11900.00 81.20 348.35 8705.16 11925.00 78.59 346.85 8709.54 11950.00 75.99 345.32 8715.04 11975.00 73.39 343.76 8721.64 12000.00 70.81 342.16 8729.33 12025.00 68.24 340.50 8738.07 12050.00 65.69 338.78 8747.85 12075.00 63.16 337.00 8758.64 12100.00 60.65 335.13 8770.42 12125.00 58.17 333.17 8783.14 12143.00 56.41 331.69 8792.87 12150.00 55.68 331.18 8796.78 12175.00 53.10 329.29 8811.33 12200.00 50.56 327.27 8826.78 12225.00 48.05 325.10 8843.08 12250.00 45.59 322.74 8860.19 12274.93 43.19 320.20 8878.00 12275.00 43.18 320.19 8878.05 12300.00 40.83 317.40 8896.63 12325.00 38.56 314.33 8915.87 12350.00 36.37 310.95 8935.71 12375.00 34.29 307.21 8956.11 12400.00 32.34 303.06 8977.00 12425.00 30.54 298.46 8998.33 12449.95 28.92 293.38 9020.00 12450.00 28.91 293.37 9020.04 J)a~:',J'12t2002 .". ' ',., ',',' . -",tbne~"4~:Ø~;3~- .,' ,',.," < ",: ).)~,~ ',. ê~....t. ~)R~Ç~AA~:. ' W~\:,:01~t2f,tl'\Je~()r1Þ . Ye~~ ",).~e~~~~~: - -'$Y~t .,~~,$(iléll:~Y~I" " '~~~!,.~$~I(ef~~~ "., , W~II,'N(}~qo¡;~W.O()Azi), ",,' , $.rv~y:~.I~~~Ji~~tb9~: - .. Minimùm,OuJ'ýatórEf' . : Db: Qi:ê;1çJe - 3 226.99 5978.70 5940511.58 704059.25 2161.10 12.00 209.00 MWD 251.56 5974.61 5940536.03 704054.52 2183.00 12.00 209.02 MWD 275.90 5969.92 5940560.24 704049.19 2204.48 12.00 209.15 MWD 299.93 5964.64 5940584.12 704043.27 2225.49 12.00 209.34 MWD 323.60 5958.78 5940607.63 704036.79 2245.96 12.00 209.60 MWD 346.84 5952.35 5940630.69 704029.76 2265.84 12.00 209.94 MWD 369.58 5945.38 5940653.24 704022.20 2285.07 12.00 210.35 MWD 391.77 5937.89 5940675.22 704014.12 2303.61 12.00 210.84 MWD 413.34 5929.89 5940696.57 704005.56 2321.40 12.00 211.42 MWD 434.23 5921.41 5940717.23 703996.53 2338.39 12.00 212.10 MWD 454.38 5912.46 5940737.14 703987.06 2354.54 12.00 212.87 MWD 473.75 5903.09 5940756.26 703977.18 2369.80 12.00 213.75 MWD 487.18 5896.08 5940769.49 703969.82 2380.21 12.00 214.74 5 492.28 5893.30 5940774.52 703966.92 2384.13 12.00 210.00 MWD 509.92 5883.22 5940791.89 703956.37 2397.53 12.00 210.28 MWD 526.64 5872.90 5940808.33 703945.61 2409.98 12.00 211.39 MWD 542.39 5862.35 5940823.80 703934.66 2421.44 12.00 212.64 MWD 557.13 5851.63 5940838.25 703923.55 2431.88 12.00 214.05 MWD 570.77 5840.77 5940851.60 703912.34 2441.24 12.00 215.66 01-12A T 570.81 5840.74 5940851.64 703912.31 2441.27 12.00 217.48 MWD 583.40 5829.73 5940863.93 703900.97 2449.59 12.00 217.49 MWD 594.86 5818.62 5940875.10 703889.57 2456.81 12.00 219.57 MWD 605.17 5807.45 5940885.11 703878.13 2462.91 12.00 221.93 MWD 614.29 5796.24 5940893.93 703866.68 2467.89 12.00 224.61 MWD 622.19 5785.02 5940901.54 703855.26 2471.71 12.00 227.66 MWD 628.87 5773.83 5940907.92 703843.90 2474.38 12.00 231.13 MWD 634.29 5762.72 5940913.04 703832.65 2475.89 12.00 235.05 01-12A T 634.30 5762.70 5940913.05 703832.63 2475.89 12.00 239.47 TD 'J '. All Measurements are from top of Riser top of bag bttm of bag middle of slips middle of pipes ~ middle of flow cross ,~ middle of blind/shears middle of pipe/slips ) ~ Q) C/) .- a: ~r.er Blind/Shears I 2 3/8" combi ram/slips Mud Cross variable bore pipe 3 1/2"-27/8" 2 3/8" combi ram/slips I lî ~'~ J!r~ Flow Tee 9/5/2002 BAG 7 1/16" 5000psi '. ,..........,...,....,. ,/ TOTs ""","""'.7 1 /16" 5000psi ........... ,-., Mud Cross 7 1/16" 5000psi --- ,..,.......,'....,... / TOTs ""","""'.7 1 /16" 5000psi ........... H DATE 8/01/02 207042 DATE 8/01/02 CHECK NO. H207042 INVOICE I CREDIT MEMO VENDOR DISCOUNT NET DESCRIPTION GROSS H CK0731021 Permit To Drill Fee $100.00 o\-\~Pt E '>,.~ E F , ;(:.¡:M :'" n /' "':0> ¡Tì , I (»' L "!.,, \,) ) PIs contact Sondr> a X4750 Atasl<a Oil & Gas Com» conìlmSSH,H~ S tewman Anchoragr. for check picku;> TOTAL .... $100.00 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TO THE ORDER OF /. ~ 333 W 7th Ave, ste 100 Anchorage, AK 99501 «,..:: ".'\.:::::::. :.: :':,::,:::~:\;~,::~~~':~~.~::::~.:i.:: :i\:: ~.:~ :.....,..,~ .~ ::.¡¡....¡~-(,....<>...."..... j&.!::gi:}r{§>:i;~~~;~~~:~;;::~;(n;i III 20 ?o L. 2111 1:0 L. ~ 20 j8 q 51: 008 L. ~ ~ qUI TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJt,f/ L 01- ).2.. A PTD# 202-- /'17- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing weD Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY Q,)( WELL NAMEh/../ /J/"/~ A PROGRAM: Exp - Dev - Redrll ~ Re-Enter - Serv - Wellbore seg- FIELD & POOL .. ~6/,) "" INIT CLASS LJpl'.J1 /--, ï GEOL AREA ?Fr"J UNIT# //6-<' ð ON/OFF SHORE ~.v ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . (( N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N A.I1- O/;l¿..., 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ¡'//rl'?-,- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . " . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. W ell located w/in area & strata authorized by injection order # ~ Y Y. A.J. J4 . (Service Well Only) 14. All wells w/in 'XI mile area of review identified. . . . . . . . .. T N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . '¥-N- 16. Surface casing protects all known USDWs. . . . . . . . . . . "¥-N'"' 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥-N-tJ(Æ- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~. .. N 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . .. . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N C-T{)tA.. 22. If a re-drill, has a 10-403 for abandonment been approved. .. ~ Y N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . élJ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥--N- rI-/Æ- 25. Drilling fluid program schematic & equip list adequate. . . . . !. N m 1M ~'7 r 111 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N .- 27. BOPE press rating appropriate; test to ~SOO psig. N ¡1It<; ¡') 2.. 2. -f 0 y?~J.. I I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N i¡J~~ q i¿. Ol,. 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . Y QV 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N-ALlA- Y([) }1 AI.¡Q. APPR DATE (Service Well Only) GEOLOGY APPR DATE ,1ft i ~¡~ (Exploratory Only) Rev: 07/12/02 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH "'.::- UIC ENGINEER JBR SFD- WGA W4iY MJW G:\geology\perm its\checklist.doc COMMISSIONER: COT DTS °Jjl7joè ') I Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. Î! ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 28 14:39:35 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/03/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments........... ..... .STS LIS ') åod-) 9;¿ 11(0109 Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/03/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22171 S. LATZ WHITLOW/MCCA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 5 AK-MW-22171 S. LATZ WHITLOW/MCCA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 7 AK-MW-22171 S. LATZ SEVCIK/MCCAR # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: 1-12A 500292026901 BP Exploration Sperry Sun 28-MAR-03 MWDRUN 2 AK-MW-22171 S. LATZ WHITLOW/MCCA MWD RUN 6 AK-MW-22171 S. LATZ SEVCIK/MCCAR 8 iON 15E 780 (Alaska) Inc. MWDRUN 4 AK-:-MW-22171 S. LATZ WHITLOW/MCCA MWDRUN 7 AK-MW-22171 S. LATZ SEVCIK/MCCAR ) ) FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 755 73.00 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 9.625 10965.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. MWD RUNS I, 2 AND 4 - 6 COMPRISED DIRECTIONAL WITH GAMMA MODULE (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 7 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4). 5. AFTER THE COMPLETION OF RUN 7, A MAD PASS WAS PERFORMED ACROSS THE ENTIRE WELL WHILE POOH. (BIT DEPTHS 11081' - 12580') RESISTIVITY DATA ACQUIRED DURING THIS PASS OVER THE RUNS 1 - 6 INTERVAL ARE INCLUDED WITH THE MERGED DATASET. MAD PASS DATA ACQUIRED ACROSS THE RUN 7 INTERVAL ARE INCLUDED AS A SEPARATE MAD PASS PRESENTATION. 6. MAD PASS DATA (DGR AND EWR4 INDEPENDENTLY) WERE DEPTH CORRECTED TO THE DRILLED DATA. 7. LOG AND MERGED DIGITAL DATA (MWD-MERGED & DEPTH CORRECTED MAD-MERGED) ONLY WERE DEPTH SHIFTED TO THE SCHLUMBERGER MEMORY CNL OF 12/30/2002, PER THE 1/20/2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 2 AND 4 - 7 REPRESENT WELL 1-12A WITH API#: 50-029-20269-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12580'MD / 9071'TVDSS. SROP = SMOOTHED SRAT = SMOOTHED SGRC = SMOOTHED SGRD = SMOOTHED SEXP = SMOOTHED SESP = SMOOTHED SEMP = SMOOTHED SEDP = SMOOTHED SFXE = SMOOTHED RATE OF PENETRATION WHILE DRILLING. TOOL SPEED WHEN NOT DRILLING. GAMMA RAY COMBINED. NATURAL GAMMA RAY. PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . FORMATION EXPOSURE TIME (RELATIVE TO SEDP) . AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name...... ...... .STSLIB.OOl Service Sub Level Name. . . Version Number.... .,... ..1.0.0 Date of Generation..... ..03/03/28 ) Maximum Physical Record..65535 File Type.............. ..LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP GR RPM RPS FET RPD RPX $ 1 ) clipped curves¡ all bit runs merged. .5000 START DEPTH 10942.0 10958.5 11058.5 11058.5 11058.5 11058.5 11058.5 STOP DEPTH 12582.0 12537.5 12551.5 12551.5 12551.5 12551.5 12551.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 10958.5 10970.0 10973.0 10978.0 10985.0 10988.0 10994.0 10995.5 10997.5 11004.5 11009.0 11011.5 11014.5 11027.0 11031.5 11033.5 11036.0 11039.0 11042.5 11046.0 11051.0 11057.0 11061.0 11067.5 11072.5 11078.5 11085.0 11092.5 11097.5 11111.5 11119.0 11121.5 11126.5 11130.5 11136.0 11139.0 11143.5 11149.0 DEPTH GR 10961.5 10973.0 10977.0 10982.5 10988.5 10991.0 10997.5 10999.0 11002.0 11008.0 11013.0 11015.0 11018.0 11030.5 11033.0 11035.5 11039.0 11042.0 11044.5 11046.5 11050.0 11053.0 11059.0 11066.0 11070.0 11077.0 11083.5 11091.5 11095.5 11109.5 11119.5 11121.5 11125.0 11128.0 11133.5 11137.5 11143.5 11147.5 ) ') 11152.0 11151.0 11154.5 11152.5 11156.5 11155.5 11161.5 11160.0 11168.0 11166.5 11177.0 11176.0 11189.5 11188.0 11204.0 11203.5 11213.0 11211.5 11217.0 11217.0 11219.0 11218.5 11231.0 11233.5 11251.0 11252.5 11262.5 11264.0 11265.5 11266.0 11269.0 11269.0 11274.0 11273.5 11275.0 11274.5 11277.5 11276.0 11279.5 11277.5 11280.5 11279.0 11286.5 11285.0 11288.0 11287.0 11290.5 11290.0 11293.0 11292.5 11294.0 11294.0 11300.0 11298.5 11307.0 11306.5 11308.0 11309.0 11319.5 11321.0 11322.0 11324.0 11331.0 11333.0 11333.5 11335.5 11335.0 11337.0 11336.5 11338.5 11339.5 11342.5 11343.5 11345.0 11352.5 11352.0 11354.5 11354.5 11364.5 11365.0 11369.5 11368.0 11371.0 11370.5 11377.0 11377.5 11378.5 11380.0 11388.5 11388.5 11390.0 11390.5 11391.0 11393.5 11393.0 11396.0 11404.0 11407.0 11405.5 11409.0 11408.0 11410.0 11416.5 11416.0 11418.5 11418.0 11422.0 11421.0 11425.5 11424.5 11428.5 11426.5 11432.0 11429.5 11437.0 11434.5 11457.0 11454.5 11460.5 11458.0 11471.0 11467.5 11473.0 11469.0 11474.5 11471.0 11485.0 11482.0 ') ) 11486.0 11484.0 11488.0 11487.0 11490.0 11489.5 11491.5 11491.5 11497.5 11495.0 11504.0 11506.5 11505.5 11507.5 11509.5 11510.5 11518.5 11518.5 11528.0 11528.5 11529.0 11530.0 11531.0 11531.5 11540.5 11538.5 11544.0 11543.5 11546.0 11545.5 11549.5 11548.5 11551.5 11549.5 11553.5 11553.5 11557.0 11556.0 11562.0 11561.0 11564.5 11562.5 11569.0 11565.5 11577.0 11573.0 11578.5 11575.0 11580.5 11576.5 11584.0 11582.5 11590.0 11587.5 11593.5 11592.0 11599.0 11598.5 11610.5 11610.0 11622.0 11620.0 11635.0 11633.5 11639.0 11639.0 11644.0 11643.0 11667.0 11665.0 11686.5 11685.5 11693.5 11692.5 11699.0 11698.5 11703.0 11702.5 11705.5 11705.0 11723.0 11721.5 11730.5 11729.0 11735.0 11733.5 11742.0 11740.5 11753.0 11751.5 11772.0 11770.5 11774.0 11773.0 11779.5 11777.5 11782.5 11781.0 11785.0 11783.5 11793.5 11792.0 11802.5 11801.0 11805.0 11803.5 11807.5 11805.5 11816.0 11814.5 11822.0 11820.0 11824.0 11821.5 11825.5 11823.5 11827.0 11825.5 11835.5 11835.0 11837.5 11836.0 11839.0 11838.0 11854.0 11853.5 11855.5 11855.0 ) ) 11858.0 11856.5 11859.0 11858.5 11863.0 11862.5 11863.5 11864.0 11877.0 11877.0 11879.0 11879.0 11880.5 11881.0 11886.5 11885.5 11889.0 11889.5 11893.0 11893.5 11901.0 11901.5 11904.5 11904.5 11906.0 11906.0 11912.0 11911.5 11915.5 11914.0 11918.0 11916.0 11920.0 11918.0 11924.5 11924.0 11929.0 11928.0 11932.5 11931.0 11938.5 11936.0 11939.5 11937.5 11943.5 11941.0 11947.0 11945.0 11956.5 11955.5 11960.0 11959.5 11968.5 11969.0 11973.5 11974.5 11984.5 11983.5 11985.5 11985.5 11989.5 11989.0 11990.5 11990.5 11994.5 11995.0 12007.5 12007.5 12023.5 12023.0 12026.5 12026.0 12029.0 12028.5 12042.0 12041.0 12050.0 12049.0 12051.0 12050.5 12055.0 12053.0 12068.5 12067.0 12070.0 12069.0 12074.5 12074.5 12090.0 12091.0 12100.0 12102.5 12101.0 12103.5 12113.5 12117.0 12115.5 12119.5 12120.0 12123.0 12124.5 12126.5 12141.5 12144.5 12144.0 12147.0 12145.5 12149.0 12157.0 12160.0 12161.0 12164.0 12173.0 12175.0 12179.5 12180.5 12180.5 12182.5 12186.5 12187.5 12189.5 12192.5 12191.0 12194.5 12198.0 12200.5 12204.0 12206.5 ) ) 12211.0 12212.5 12214.5 12215.5 12216.5 12218.0 12218.0 12220.5 12220.5 12224.5 12224.0 12227.5 12229.5 12234.0 12242.0 12247.0 12245.5 12249.5 12249.0 12253.0 12251.0 12254.5 12255.0 12258.0 12267.5 12271.5 12270.0 12275.5 12273.0 12278.0 12293.5 12299.0 12295.5 12300.0 12297.0 12302.5 12299.5 12304.5 12301.0 12306.5 12302.0 12308.0 12315.5 12321.0 12319.5 12325.5 12322.0 12328.5 12324.5 12330.5 12346.5 12352.5 12351.0 12357.0 12354.0 12360.0 12355.5 12361.0 12360.5 12364.0 12364.0 12367.0 12368.5 12371.0 12372.5 12374.0 12375.0 12376.0 12377.5 12378.5 12379.5 12380.0 12381.0 12382.0 12383.5 12384.5 12385.0 12385.5 12387.5 12387.5 12393.5 12394.5 12395.0 12395.5 12398.5 12399.0 12403.0 12404.5 12409.0 12410.0 12413.5 12413.0 12416.0 12415.0 12417.5 12416.5 12419.5 12418.5 12423.0 12421.5 12426.0 12425.5 12428.5 12428.5 12434.0 12434.0 12436.5 12435.5 12440.5 12439.5 12444.0 12442.0 12445.5 12444.0 12447.0 12446.0 12448.5 12449.0 12451.0 12450.5 12452.0 12452.0 12458.0 12457.5 12461.0 12461.0 12463.0 12463.0 ) ) 12468.0 12471.0 12475.5 12479.5 12482.0 12483.0 12491.0 12494.0 12498.5 12505.0 12508.5 12510.5 12520.5 12531.0 12582.0 $ 12466.0 12470.5 12474.0 12477.5 12478.5 12480.5 12488.0 12492.0 12496.0 12502.5 12506.0 12508.5 12518.0 12528.5 12579.5 # MERGED DATA PBU TOOL MWD MWD MWD MWD MWD MWD $ SOURCE CODE BIT RUN NO 1 2 4 5 6 7 MERGE TOP 10945.0 11030.0 11044.5 11603.0 12101.5 11048.0 MERGE BASE 11059.5 11071.5 11630.0 12128.5 12387.0 12580.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point........ ..... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10942 12582 11762 3281 10942 12582 ROP MWD FT/H 0.13 430.36 79.5203 3281 10942 12582 GR MWD API 18.36 445.6 62.2715 3159 10958.5 12537.5 RPX MWD OHMM 1.84 2000 27.0665 2987 11058.5 12551.5 RPS MWD OHMM 1.94 2000 41.8957 2987 11058.5 12551.5 RPM MWD OHMM 0.54 2000 51.1946 2987 11058.5 12551.5 RPD MWD OHMM 0.09 2000 81.6515 2987 11058.5 12551.5 FET MWD HOUR 0.24 101.04 36.6484 2987 11058.5 12551.5 ) ) First Reading For Entire File......... .10942 Last Reading For Entire File......... ..12582 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.... ...... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 11048.0 11058.5 11058.5 11058.5 11058.5 11058.5 11092.5 STOP DEPTH 12536.0 12554.0 12554.0 12554.0 12554.0 12554.0 12580.0 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP 7 1 11048.0 MERGE BASE 12580.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . ) Datum Specification Block sub-type...O Name Service DEPT RAT MAD GR MAD RPX MAD RPS MAD RPM MAD RPD MAD FET MAD Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR Size Nsam 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 Rep Code 68 68 68 68 68 68 68 68 Offset 0 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11048 12580 11814 3065 11048 12580 RAT MAD FT/H 58 951 715.34 2976 11092.5 12580 GR MAD API 8.45 302.39 49.1811 2977 11048 12536 RPX MAD OHMM 1.84 2000 26.9015 2992 11058.5 12554 RPS MAD OHMM 1.94 2000 41.743 2992 11058.5 12554 RPM MAD OHMM 0.54 2000 51.0521 2992 11058.5 12554 RPD MAD OHMM 0.09 2000 81.493 2992 11058.5 12554 FET MAD HOUR 0.98 101.04 37.0972 2992 11058.5 12554 First Reading For Entire File........ ..11048 Last Reading For Entire File... ...... ..12580 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name. ..... ...... .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name. ..... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR 3 header data for each bit run in separate files. 1 .5000 START DEPTH 10945.0 10961.5 STOP DEPTH 11059.5 11032.5 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point....... ...... . Undefined Frame Spacing.................... .60 .1IN Max frames per record... ......... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 24-0CT-02 Insite 4.3 Memory 11060.0 10917.0 11060.0 .0 .0 TOOL NUMBER 82758 3.750 .0 Biozan 8.60 60.0 8.8 22000 .0 .000 .000 .000 .000 .0 155.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 ) ') GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10945 11059.5 11002.3 230 10945 11059.5 ROP MWD010 FT/H 0.13 39.72 21.263 230 10945 11059.5 GR MWD010 API 180.34 445.6 301.169 143 10961.5 11032.5 First Reading For Entire File........ ..10945 Last Reading For Entire File.......... .11059.5 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name. . . Version Number.... ...... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11030.0 ROP 11060.0 $ 4 header data for each bit run in separate files. 2 .5000 STOP DEPTH 11046.5 11071.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 25-0CT-02 Insite 4.3 Memory 11074.0 11060.0 11074.0 .0 .0 ) # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point.... ......... . Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER 82758 3.750 10965.0 Biozan 8.60 65.0 8.8 22000 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 ) .0 141.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11030 11071.5 11050.8 84 11030 11071.5 ROP MWD020 FT/H 0.54 16.85 6.59833 24 11060 11071.5 GR MWD020 API 133.67 240.75 180.312 34 11030 11046.5 First Reading For Entire File........ ..11030 Last Reading For Entire File.......... .11071.5 ') ) File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 11044.5 11072.0 STOP DEPTH 11602.5 11630.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 26-0CT-02 Insite 4.3 Memory 11630.0 11074.0 11630.0 49.5 89.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10965.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: Flo Pro 8.80 60.0 8.5 ') ) MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 24000 5.2 .000 .000 .000 .000 .0 141.4 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point......... .....Undefined Frame Spacing.................... .60 .1IN Max frames per record....... ..... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11044.5 11630 11337.3 1172 11044.5 11630 ROP MWD040 FT/H 1.31 157.84 72.5525 1117 11072 11630 GR MWD040 API 24.38 310.1 54.3598 1117 11044.5 11602.5 First Reading For Entire File......... .11044.5 Last Reading For Entire File......... ..11630 File Trailer Service name...... ...... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 ') Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 ) header data for each bit run in separate files. 5 .5000 START DEPTH 11603.0 11630.5 STOP DEPTH 12101.0 12128.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 27-0CT-02 Insite 4.3 Memory 12129.0 11630.0 12129.0 68.6 86.0 TOOL NUMBER 69706 3.750 10965.0 Flo Pro 8.80 65.0 8.5 24000 .0 .000 .000 .000 .000 .0 145.0 .0 .0 ) ') # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units. ......... .Feet Data Reference Point............. . Undefined Frame Spacing. ... ................ .60 .1IN Max frames per record.. .......... . Undefined Absent value.. .... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11603 12128.5 11865.8 1052 11603 12128.5 ROP MWD050 FT/H 0.46 242.8 87.4232 997 11630.5 12128.5 GR MWD050 API 21.57 168.89 49.5396 997 11603 12101 First Reading For Entire File... .... ...11603 Last Reading For Entire File......... ..12128.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name.. .......... .STSLIB.007 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 7 header data for each bit run in separate files. 6 .5000 ') FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 12101.5 12129.0 STOP DEPTH 12359.0 12387.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL~TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units...... ... ..Feet Data Reference Point............ ..Undefined Frame Spacing.... ............ .... .60 .1IN Max frames per record............ .Undefined Absent value..... ..... ........... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 28-0CT-02 Insite 4.3 Memory 12387.0 12129.0 12387.0 53.0 61.8 TOOL NUMBER 82758 3.750 10965.0 Flo Pro 8.60 65.0 9.0 23000 5.0 .000 .000 .000 .000 .0 149.0 .0 .0 ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12101.5 12387 12244.3 572 12101.5 12387 ROP MWD060 FT/H 8.77 141.5 86.3705 517 12129 12387 GR MWD060 API 19.84 123.04 29.8972 516 12101.5 12359 First Reading For Entire File........ ..12101.5 Last Reading For Entire File.......... .12387 File Trailer Service name. .......... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/03/28 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 8 header data for each bit run in separate files. 7 .5000 START DEPTH 12338.5 12351.5 12351.5 12351.5 12351.5 12351.5 12387.5 STOP DEPTH 12535.0 12549.0 12549.0 12549.0 12549.0 12549.0 12579.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 28-0CT-02 VERSION: Insite ) DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units. ......... .Feet Data Reference Point. '" ......... . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record.. .......... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 4.3 Memory 12580.0 12387.0 12580.0 28.6 54.0 TOOL NUMBER 69706 144955 3.750 10965.0 Flo Pro 8.80 65.0 8.5 23000 6.0 .190 .100 .140 .170 72.0 148.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 ) FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12338.5 12579.5 12459 483 12338.5 12579.5 ROP MWD070 FT/H 1.02 430.36 108.211 385 12387.5 12579.5 GR MWD070 API 18.36 152.46 61.9046 394 12338.5 12535 RPX MWD070 OHMM 2.59 43.49 10.6171 396 12351.5 12549 RPS MWD070 OHMM 2.65 40.09 10.9426 396 12351.5 12549 RPM MWD070 OHMM 2.74 37.42 11.1369 396 12351.5 12549 RPD MWD070 OHMM 3.08 32.76 11.5612 396 12351.5 12549 FET MWD070 HOUR 0.24 10.43 2.61992 396 12351.5 12549 First Reading For Entire File........ ..12338.5 Last Reading For Entire File......... ..12579.5 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/03/28 Maximum Physical Record..65535 File Type......... ...... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name...... ...... .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type......... ..... ..LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET RAT $ 9 header data for each pass of each run in separate files. .5000 7 1 START DEPTH 11048.0 11055.5 11055.5 11055.5 11055.5 11055.5 11092.5 STOP DEPTH 12536.0 12551.5 12551.5 12551.5 12551.5 12551.5 12580.0 # LOG HEADER DATA DATE LOGGED: 28-0CT-02 ') SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point.... .... ... ...Undefined Frame Spacing...... ............. ..60 .1IN Max frames per record... ......... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Insite 4.3 Memory 12580.0 11040.0 12580.0 28.6 54.0 TOOL NUMBER 69706 144955 3.750 10965.0 Flo Pro 8.80 65.0 8.5 23000 6.0 .190 .100 .140 .170 72.0 148.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD071 FT/H 4 1 68 4 2 GR MAD071 API 4 1 68 8 3 RPX MAD071 OrIMM 4 1 68 12 4 RPS MAD071 OrIMM 4 1 68 16 5 ) ) RPM MAD071 OHMM 4 1 68 20 6 RPD MAD071 OHMM 4 1 68 24 7 FET MAD071 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11048 12580 11814 3065 11048 12580 RAT MAD071 FT/H 58 951 715.34 2976 11092.5 12580 GR MAD071 API 8.45 302.39 49.1811 2977 11048 12536 RPX MAD071 OHMM 1.84 2000 27.563 2993 11055.5 12551.5 RPS MAD071 OHMM 1.94 2000 43.2181 2993 11055.5 12551.5 RPM MAD071 OHMM 0.54 2000 52.5953 2993 11055.5 12551.5 RPD MAD071 OHMM 0.09 2000 82.8401 2993 11055.5 12551.5 FET MAD071 HOUR 0.98 101.04 37.2509 2993 11055.5 12551.5 First Reading For Entire File......... .11048 Last Reading For Entire File.......... .12580 File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0 3 / 0 3 / 2 8 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments..... ...... ..... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .03/03/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File