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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,196.0 12/29/2014 3S-15 lehallf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: P&A marker plate Welded 5'7" below OG 9/8/2020 3S-15 mouser Casing Strings Casing Description CONDUCTOR Insulated 30" OD (in) 16 ID (in) 15.06 Top (ftKB) 39.1 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 39.1 Set Depth (ftKB) 3,561.3 Set Depth (TVD) … 2,609.6 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.1 Set Depth (ftKB) 8,404.1 Set Depth (TVD) … 6,193.5 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 39.1 Set Depth (ft… 7,807.7 Set Depth (TVD) (… 5,606.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 496.2 495.4 6.31 NIPPLE CAMCO DS NIPPLE 2.875 7,713.5 5,515.0 16.00 SLEEVE BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO (OPENED 12/30/2014) 2.812 7,759.1 5,559.1 14.44 SEAL ASSY LOCATOR SUB AND PBR SEAL ASSEMBLY (SPACED OUT 2' ABOVE FULLY LANDED) 2.992 7,761.1 5,561.0 14.36 PBR BAKER 80-40 PBR 3.000 7,774.8 5,574.3 13.83 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 3.000 7,775.7 5,575.2 13.80 PACKER BAKER SAB-3 PACKER 3.250 7,780.7 5,579.9 13.61 MILLOUT 80-40 MILLOUT EXTENSION 3.720 7,786.8 5,585.9 13.37 XO BUSHING CROSSOVER BUSHING 3.000 7,799.8 5,598.6 12.87 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO 2.750 7,806.8 5,605.4 12.60 WLEG WLEG w/ SHEAR OUT SUB 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 38.9 38.9 0.22 P&A MARKER PLATE 3S-15 P&A Marker plate 9/8/2020 0.000 7,723.0 5,524.2 15.70 TUBING LEAKS TUBING LEAKS IDENTIFIED BY EL LEAK DETECT LOG. LEAK IDENTIFIED IN CMU AND MULTIPLE LEAKS IN TBG JT BELOW CMU FROM 7723'-7753' RKB 9/16/2015 2.990 7,786.9 5,586.0 13.37 Cement Retainer 3.5" Cement Retainer 2.75"x1.46" long 6/14/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,692.0 7,696.0 5,494.4 5,498.2 6/18/2020 4.0 TBG PUNCH 2.0" X 4' TUBING PUNCH 8,103.0 8,118.0 5,896.5 5,911.3 C-4, 3S-15 3/4/2003 6.0 IPERF 2.5" HSD, 60 deg phase, 1000 psi Underbalanced Frac Summary Start Date 12/24/2004 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 12/24/2004 Top Depth (ftKB) 8,103.0 Btm (ftKB) 8,118.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 7,808.0 8,218.0 5,606.6 6,009.8 Plug #1 - cement PC, across perfs to tubing tail Pumped 25.6 bbls of 15.8 ppg Class G below cement retainer squeezing cement to the pefs. 7,749.0 7,808.0 5,549.3 5,606.6 Plug #1 - Tubing, from 7,808 to 7,749ft KB Pumped 1 bbl above retainer and 25.6 bbls below retainer set at 7790' - 15.8 clas G 360.0 3,561.0 359.8 2,609.4 Plug #2 - OA Downsqueeze 120 BBLS @15.8 Permafrost cement 39.1 7,696.0 39.1 5,498.2 Plug #3 - IA, from punch to surface 15.8 Class "G" Cement 39.1 7,696.0 39.1 5,498.2 Plug #3 - tubing, from punch to surface 15.8 Class "G" Cement 39.1 360.0 39.1 359.8 Cement plug 15.6 Class "1" Cement (Top Off) 8/30/2020 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,527.4 2,590.5 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 11/13/2003 4:00 2 5,513.0 3,819.0 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 11/13/2003 4:00 3 6,765.1 4,675.1 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 11/13/2003 11:30 4 7,429.0 5,248.5 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 4/3/2004 10:30 5 7,662.1 5,465.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/4/2004 4:30 Notes: General & Safety End Date Annotation 9/8/2020 NOTE: AOGCC Inspector Guy Cook Witnessed marker plate information and welding. 3S-15, 9/29/2020 2:39:32 PM Vertical schematic (actual) PRODUCTION; 39.1-8,404.1 FRAC; 8,103.0 IPERF; 8,103.0-8,118.0 Plug #1 - cement PC, across perfs to tubing tail; 7,808.0 ftKB WLEG; 7,806.8 NIPPLE; 7,799.8 Cement Retainer; 7,786.9 XO BUSHING; 7,786.8 MILLOUT; 7,780.7 PACKER; 7,775.7 ANCHOR; 7,774.8 PBR; 7,761.1 SEAL ASSY; 7,759.1 Plug #1 - Tubing, from 7,808 to 7,749ft KB; 7,749.0 ftKB TUBING LEAKS; 7,723.0 SLEEVE; 7,713.5 TBG PUNCH; 7,692.0-7,696.0 GAS LIFT; 7,662.1 GAS LIFT; 7,429.0 GAS LIFT; 6,765.1 GAS LIFT; 5,513.0 SURFACE; 39.1-3,561.3 GAS LIFT; 3,527.4 NIPPLE; 496.2 Plug #2 - OA Downsqueeze; 360.0 ftKB CONDUCTOR Insulated 30"; 39.0-108.0 Cement plug; 39.1 ftKB Plug #3 - IA, from punch to surface; 39.1 ftKB Plug #3 - tubing, from punch to surface; 39.1 ftKB P&A MARKER PLATE; 38.9 KUP PROD KB-Grd (ft) 33.65 Rig Release Date 1/25/2003 3S-15 ... TD Act Btm (ftKB) 8,404.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044400 Wellbore Status PROD Max Angle & MD Incl (°) 58.41 MD (ftKB) 2,542.65 WELLNAME WELLBORE3S-15 Annotation Last WO: End DateH2S (ppm) 100 Date 9/26/2014 Comment SSSV: NIPPLE Notes: General & Safety End Date Annotation 8/30/2020 NOTE: P&A Cement top off 7/22/2004 NOTE: MITIA 3000 psi PASSED 3S-15, 9/29/2020 2:39:32 PM Vertical schematic (actual) PRODUCTION; 39.1-8,404.1 FRAC; 8,103.0 IPERF; 8,103.0-8,118.0 Plug #1 - cement PC, across perfs to tubing tail; 7,808.0 ftKB WLEG; 7,806.8 NIPPLE; 7,799.8 Cement Retainer; 7,786.9 XO BUSHING; 7,786.8 MILLOUT; 7,780.7 PACKER; 7,775.7 ANCHOR; 7,774.8 PBR; 7,761.1 SEAL ASSY; 7,759.1 Plug #1 - Tubing, from 7,808 to 7,749ft KB; 7,749.0 ftKB TUBING LEAKS; 7,723.0 SLEEVE; 7,713.5 TBG PUNCH; 7,692.0-7,696.0 GAS LIFT; 7,662.1 GAS LIFT; 7,429.0 GAS LIFT; 6,765.1 GAS LIFT; 5,513.0 SURFACE; 39.1-3,561.3 GAS LIFT; 3,527.4 NIPPLE; 496.2 Plug #2 - OA Downsqueeze; 360.0 ftKB CONDUCTOR Insulated 30"; 39.0-108.0 Cement plug; 39.1 ftKB Plug #3 - IA, from punch to surface; 39.1 ftKB Plug #3 - tubing, from punch to surface; 39.1 ftKB P&A MARKER PLATE; 38.9 KUP PROD 3S-15 ... WELLNAME WELLBORE3S-15 I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg��` "I DATE: 9/10/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: Location Inspection Petroleum Inspector KRU 3S-15 Conoco/Phillips PTD 2022540; Sundry 320-049 9/10/2020: 1 arrived on site and met with Roger Mouser with CPAI. I looked over the site and everything looked to be completed except some of the components of the well - house for 3S-15 were still on location. These pieces were to be picked up by the well ' maintenance crew shortly. No follow-up needed. I took some photographs of the area and left location. Attachments: Photos (3) 2020-0910_Location_KRU_3R-15_gc.docx Pagel of 3 I 1� `ted Js Y•��- �� .y �p. J. r e � tri �u i�� '} a� .wig, .,,,. �•-�i"r'. '.� }' �...w �`y 'lit '�� J y•R 1 O O1 O O N 0 N MEMORANDUM TO: Jim Regg �I�7 1 P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission *Z-14-tt, DATE: 9/08/20 FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-15 - ConocoPhillips Alaska Inc. PTD 2022540; Sundry 320-049 9/08/2020: 1 arrived on site and met with Roger Mouser with CPAI. We took measurements of the cut-off wellhead and also took measurements from the cut-off casing to pad level. The cut-off casing was confirmed to be 5 ft 7 inches below tundra level. I inspected the abandonment which had good cured cement to surface. I inspected the marker plate and all the information was correct except I had them add KRU to the well name. The KRU was added after the "3S-15" on the plate. I thought that was sufficient and let them know to make sure they included the full well name on the identification plates in the future. I gave them the go-ahead to weld on the identification plate and inspected the installation when the welder was done. The welds appeared to be continuous and looked to have good penetration into the casing and into the plate, sealing the wellbore from the outside environment. Attachments: Photos (5) 2020-0908_Surface_Abandon_KRU_3 S-15_gc.docx Pagel of 4 t � , -' ib:f'i ,�� J. .. a •� :! 1 # t r t# MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ' 6(ol2rJW P.I. Supervisor 666 t FROM: Guy Cook Petroleum Inspector Section: 18 Township: Drilling Rig: N/A Rig Elevation: Operator Rep: John Condio Casing/Tubing Data (depths are MD) DATE: June 18, 2020 SUBJECT: Plug Verification KRU 3S-15 Conoco/Phillips Alaska PTD 2022540; Sundry 320-049 12N Range: 8E N/A Total Depth: 8420 ft MD Suspend: Conductor: 16" ' 0. D. Shoe@ 108 Feet Surface: 9 5/8" O.D. Shoe@ 3561 Feet Intermediate: Feet 0. D. Shoe@ Feet Production: 7" 0. D. Shoe@ 8404 - Feet Liner: 0. D. Shoe@ Feet Tubing: 3.5" 0. D. Tail@ 7�Feet Plugging Data: Test Data: Meridian: Umiat Lease No.: ADL0380106 P&A: X ' Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Stm Depth To MW Above Verified Perforation Retainer 7786 ft MD 7747 ft MD ' 6.8 ppg Wireline tag 290 290 Initial 15 min 30 min 45 min Result Tubing 1585 1570 1565 - OA 370 360 360 IA 710 710 710 - P OA 290 290 290 Initial 15 min 'An min 4.r min Pac'df Tubing 135 135 - 135 IA 1650 1580 - 1545 - P OA 370 360 360 Remarks: The first tag of the cement was at 7747 ft MD (including 16.5 ft correction for wireline) and the 5 ft x 2.25 inch drive down bailer was driven down two feet to stop at 7749 ft MD. The sample recovered showed good cement. The MIT -T was performed next and passed with no issues. The MIT -IA followed and the first test passed AOGCC requirements, but failed CPAI's. A second test was performed and it passed both CPAI's and AOGCC's requirments. The bbls in/bbls out for the MIT -T was 14 bbls in and ✓ 14 bbls out. The bbls in/bbls out for the MIT -IA was approxiamately 6 bbls in and 6 bbls out. The second cement tag was at 7749 ft MD so there was no movement of the cement caused by the MITs. I contacted Victoria Loepp with the AOGCC prior to the second cement tag and told her about the results of the MITs to keep her in the loop. Attachments: none rev. 11-28-18 2026-0618 Plug_Verification_KRU 3S-15_gc THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-15 Permit to Drill Number: 202-254 Sundry Number: 320-049 Dear Ms. Simek: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Va DATED this S day of February, 2020. RBDMS6��FEB 0 7 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEiVED JAN 2 v 2020 $27'-S ti s ) 2c7 AOGCC 1. Type of Request: Abandon ❑' Plug Perforations EI Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[-] Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhilll S Alaska Inc. Exploratory ❑ Development El Stratigraphic ❑ Service ❑ 202-254 ' 3. Address: 6. API Number. , P. O. Box 100360, Anchorage, Alaska 99510 50-103-20444-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A 3S-15 Will planned perforations require a spacing exception? Yes ❑ No DKRU ' 9. Property Designation (Lease Number): �., f ' "P 10. Field/Pool(s): ADL 380106 NDL390107L5 Kuparuk River Field / Kuparuk River Oil Pool 11. -PT:72 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,420' 6,209' 8212 6004 2575psi 7799.8 NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 108' 108' Surface 3,532' 95/8 3,561' 2,610' Production 8,377' 7" 8,404' 6,193' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8103-8118 5896-5911 3.500" L-80 7,808' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER SAB -3 PACKER MD= 7776 TVD= 5575 12. Attachments: Proposal Summary 0 Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development [A Service ❑ 14. Estimated Date for 2/3/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned M 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name. Jill Simek Authorized Tide: Staff Well Integrity Engineer Contact Email: Jill.Smek@cop.com Contact Phone: (907) 263-4131 Authorized Signature: Date: 1 i�" 7,D COMMI SION OSE ONLY Conditions of approval: Not ommission so that a representative may witness Sundry Number: Plug Integrity LVI BOP Test ❑ Mechanical Integrity Test r�r/ Location Clearance ❑ Other: repo,"- PJ1,7 ;V Al/rs tay to �ccP� . Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: '" 4,0 ;7,RBDMSO'. FEB 0 7 LOLO '"1. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date ORIGINAL ///,//� wsubmit Form and Form 10-403 Revised 4/20 �A proved application is valid for 12 months from the date of approval. / Attachments in Duplicate _7'1/,`D nil, o% n ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska Alaska Oil & Gas Conservation Commission 333 West Th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: 27 January 2020 3S-15 is a Kuparuk C -sand producer drilled and completed in 2003. In October 2007 the well stopped producing and was shut in. It was returned to production briefly in 2017 and produced 100% water until it was diagnosed with multiple tubing leaks. With the resource depleted, a P&A of 3S-15 is recommended, which will allow for slot recovery for the grassroots Torok producer 3S- 615. The well is completed with 3 %" tubing to 7,808ft KB and T' production casing to 8,404ft KB. 9- 5/8" surface casing is set at 3,561 ft KB. C4 perforations are at 8,103ft to 8,118ft KB. Tubing leaks have been identified from 7,723ft KB to 7,753ft KB, and a sliding sleeve, in the open position, is located at 7,714ft K . Per this procedure, P&A operations will be performed with coil tubing to pump cement through a cement retainer, across the perforations, and into the tubing, to an approximate depth of 7,675ft KB. A cement downsqueeze will follow to place approximately 3,561ft of cement in in the surface casing x production casing annulus (OA). Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) and cement placed in the tubing and tubing x production casing annulus (IA) to surface. The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Please refer to the attached procedure for more details. If you have any questions or require any further information, please contact me at 263-4131. Sincerely, U V4— ill limek ff Well Interventions Engineer ConocoPhillips 3S-15 P&A Permit to Drill #: 202-254 Per this procedure, P&A operations will be performed with coil tubing to pump cement through a cement retainer, across the perforations, and into the tubing, to an approximate depth of 7,675ft KB. A cement downsqueeze will follow to place approximately 3,561ft of cement in in the surface casing x production casing annulus (OA). Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) and cement placed in the tubing and tubing x production casing annulus (IA) to surface. The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Proposed P&A: Slickline / Little Red: Objective: Pull CA -2 plug, injectivity test, drift for retainer, establish OA LLR 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH and pull CA -2 plug at 7,800' KB. 4. Rig up LRS, pump 30 bbls diesel to verify injectivity for cementing operations 2 bpm at 2,OOOpsi). DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. Establish/confirm OA LLR for cement downsqueeze (previous LLR = 1.5bpm at 1150psi, performed July/2016) 6. RIH with 2.75" x 15' dummy mechanical cement retainer tool string, down to 7790' KB (middle of tubing pup above D -nipple). 7. RDMO Coiled Tubing / Cementing: Objective: Plug #1 — Place a cement plug across the perforations and squeeze some cement into perforations. Cement Volume Calculations (TOC approximately 7,675' KB in tubing): • Volume in 7" casing from 100' below perforations to tubing tail: (8,218 ft - 7,808 ft) x 0.03826 bbl/ft = 15.7 bbl • Volume in 3-1/2" tubing, from tubing tail to 7,675' KB: (7,808 ft — 7,675 ft) x 0.008696 bbl/ft = 1.2 bbl • Squeeze volume: 10 bbl • Total volume: 15.7 + 1.2 + 10 = 26.9 bbl JS 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean 303 506-8462). The job is designed for 26.9 bbis of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and Cementers. Pressure test equipment as required. 5. Reference 9/22/2015 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 7,790' KB (middle of tubing pup above D - nipple), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,OOOpsi). 10. Pump 10 bbis fresh water spacer 11. Pump 25.9 bbis of 15.8 ppg Class "G" Cement. If squeeze pressure is seen before pumping total cement volume, unsting from retainer and begin next step. 12. Shut down, un -sting from retainer 13. Lay in remaining 1.0 bbl cement above retainer (equates to - 115' of cement above the retainer, leaving TOC -7,675' KB) 14. POOH above TOC. Circulate CTU clean. 15. Wash up surface equipment. RDMO. Slickline / Little Red: JS Objective: State witnessed tag of TOC, MIT -T, CMIT-TxIA, DDT -T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,675' KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT -T to 1,500 psi. Record Results. PRESSURE TEST MUST BE AOGCC WITNESSED 7. Perform CMIT-TxIA to 1,500 psi. Record results. 8. Perform DDT -T. Record Results. 9. Report issues and results to Well Interventions Engineer. 10. RDMO Do not r`aGtccs� ,'� �' MATS F,L,I. Eline / Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E -Line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 9/22/2015 schematic and tubing details for depth correlation. 4. Punch 30'-50' above TOC or as close to mid joint as possible. 5. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,OOOpsi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. Cementing: Objective: Plug #2 — OA Downsqueeze 9 5/8" x 7" annulus (OA) from surface to surface casing shoe (3,561' KB). Cement Volume Calculations: • Volume in 7" x 9 5/8" annulus: (3,561 ft) x (0.02823 bbl/ft) = 100.5 bbl • Excess: 20 bbl • Total volume: 100.5 + 20 = 120.5 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean 303 506-8462). The job is designed for 120.5 bbls of Permafrost Cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU HAL Cement Equipment and PT surface lines as required. 4. Line up down OA. 5. Pump 5 bbl of fresh water spacer. 6. Pump 120.5 bbl of Permafrost Cement. If well locks up while pumping cement, go to step 7. 7. Close OA, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 8. RDMO JS DHD: Objective: OA TOC, DDT 1. WOC for 24 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on OA. 4. Confirm OA TOC at surface. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. RDMO. Cementing: Objective: Plug #3 - Fill the tubing and IA with cement from tubing punch (-7,675' KB) to surface. We will be circulating cement down the 3'/" tubing and up the 3'/z" x 7" annulus. Cement Volume Calculations: • Volume in 3'/" x 7" annulus: (7,675 ft — 0 ft) x (0.02636 bbl/ft) = 202.3 bbl • Volume inside 3'/" tubing: (7,675 ft — 0 ft) x (0.008696 bbl/ft) = 66.7 bbl • Excess: 20 bbi • Total volume: 202.3 + 66.7 + 20 = 289 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean 303 506-8462). The job is designed for 289 bbls of 15.8# Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. MIRU cementers. PT surface equipment as required. 4. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3'/z' x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 5. Establish circulation with diesel. 6. Pump 5 bbls fresh water spacer 7. Pump 289 bbls of 15.8 ppg Class "G" cement. • Assumes tubing punch at 7,675' KB and includes 20 bbl excess. Recalculate based on actual tubing punch depth. 8. After approximately 269 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 9. Shut down pumps and close in the IA. 10. Close in the master valve, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 11. RDMO JS DHD: Objective: DDT 1. WOC for 24 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off tubing, IA, and OA to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld %" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 3S-15 PTD M 202-254 API M 50-103-20444-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. JS P&A Diagram: 3S-15 Plug & Abandonment PTD #: 202-254 J 1 I I I I IL IVM5#H40 CaROVCtOt0103 KS J, 1 GLM: DW Q 3,52T KB 9 57 56L-WMrr C8 C36M 03, 561' K5 GLM DUYOS513'K5 CM -06765' K5 DJY 0 7325' KS E)kJY07,6ET KB CMJ (G-CtQl07.716 KB TUEmg Leake 97,723'K5-7753' KB BAA SAIM P2AR 07,776 KB 2.7S C. -A Ptq 0 7.= KB WT 9.39 J45 Turing Q3C6' KB pem: 8.10-UIVKS 7-'259 L.30 Pr &cWn =R9 @&ARS KS F" Smand R4 3.5611L9- omq f eMWf W C4WAM Tried Plug rT & 1A) 7,63' KR-&jrr R 15.8 ppg C[ -G- 5't 1�v I //I y6V� / 151 Rag rPWCMUOM, CaMg. 87wrig: 8,218-7.675 �Z I��S� i58 ppg Cl36a'G' OwwtP.Et MraIT79MKS JS 1 -27 -MO ~cl~lum~er~r Schlumberger -DCS 2525 Gambell Street Suite 400 ~ ~~~ ~` ~~'~, ` t ~ ~~ ~ ~ ~~ k ~:~~~, Anchorage, AK 99503-2838 °" ATTN: Beth > <~~ti r ri NO.4957 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Co~ ~~~~ i Date BL Color CD 11 /10/08 iC-119 11978488 INJECTION PROFILE ~ 10/16/08 1 1 iJ-101 11978491 PRODUCTION PROFILE 10/19/08 1 1 3H-02 12080447 INJECTION PROFILE ~ - '~- ~- 10/24/08 1 1 3K-24 11978500 SBHP 10/26/08 1 1 1J-120 11978501 PRODUCTION PROFILE ~. 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY - 10/18!08 1 1 iH-08 12100434 INJECTION PROFILE - / 10/30/08 1 1 1 H-09 12096560 INJECTION PROFILE ~~ zC 1013 ~ `~ 1~- ('~-0 10/30/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~r7 • . . WELL LOG TRAN"SMITT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08 3S-08A 3S-08B,3S-14, - - 3S-15. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-03: do3 -00 I 1f: i4¡~/~';). Digital Log Images: 50-103-20458-00 3S-06: ():r C- 6)03 - 0 ~-::;. a: I '-IL.l d 3 Digital Log Images: 50-103-20454-00 ANNED FEB 0 1 2007 5C . 1 CD Rom 1 CD Rom 3S-06A: UIC!.... QO"3-()'tS'~ -1t I¿./L¡ Ð-I Digital Log Images: 50-103-20454-01 3S-08 3S-08A 3S-08B: dC>3 -Odd. j dó3 -O~ I dö3-043 Digital Log Im-;ges: ~ I '-I "IéJ6 I '-/4 Q~ 4LI d 1- 50-103-20450-00,01,02 1 CD Rom 1 CD Rom 3S-l4: lJI.~d6~-d!O ~IL.¡LI{:)O Digital Log Images: 50-103-20439-00 1 CD Rom 3S-l5: dDd -CJ54 1:1. /'-IL/d4 Digital Log Images: 50-103-20444-00 1 CD Rom t . Cor1ocJÂ1i11ips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 :1 ,~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 , rf> A' h(r" r-, ':~;",'~ ,¡jjÌ£,.''t.4,:\~-i.'''" ,~, ~~.¡.r t,;J 'IJ:·;·ti··..."""..- ~5 aOd-.-,~5Y. 35- ,5" Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18,2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~~~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field August 7,2006 Well Name Initial top Vol. of cement Final top of Cement top pro # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 12, 2004 1ðL{) -? 9 RE: MWD Formation Evaluation Logs 3S-15, AK-MW-30003 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~ 2C)'_{K . ,-,)- ,_/ Digital Log Images 50-103-20444-00 ~~~-J15+~-~ 1 CD Rom ~ e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker.doc 3 (J.p ~JH) DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022540 MD 8420 Well Name/No. KUPARUK RIV UNIT 3S-15 Operator CONOCOPHILLlPS ALASKA INC 5p~l¿ (òj~~\- API No. 50-103-20444-00-00 ...--TVD 6209 ~ Completion Date 3/3/2003 -- Completion Status 1-01l REQUIRED INFORMATION Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRES/DENS/Newt, CBl w/SCMT Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name -""----------- i i I I ! ¡ I i Rpt lED 0 ~.¡,.,c-Og/" ,@ D QJD 0 I : Rpt I Mud log No Log Log Scale Media Interval Start Stop Run No Directional Survey Directional Survey Cement Evaluation lA1645 LIB- Verifieation 5 Col o 8420 o 8420 7650 8192 3540 8388 rJ 11645 LIS Verification ~a.. (U¡.'lll..{ (tv(Jj S~ß ftötð \) / 2 3540 8388 LIS Verification 3540 8388 I I Rpt LIS Verification i L___ Well Cores/Samples Information: 2 3540 8388 Current Status 1-01l ç;:~ Directional su~~~~~ ..,_ (data taken from logs Portion of Master Well Data Maint) OH/ CH Received Comments A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/9/2003. ~ Open 2/26/2003 Open 2/26/2003 Case 317/2003 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 .~ Name Interval Start Stop Received Sample Set Number Comments Sent DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022540 Well Name/No. KUPARUK RIV UNIT 3S-15 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20444-00-00 MD 8420 TVO 6209 Completion Date 3/3/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ....y / N --' Daily History Received? -~ @N ffyN Formation Tops Analysis Received? l'"7'J\J ---~--- Comments: -~~ Compliance Reviewed By: Jo Date: . t{!Jp Ä~ \- .~ ) ConocóP'hillips ,~ Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 11, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 RECE\VEO JAN 1 2 2005 ... nmm\SS\on O'~ q:¡, Gas Cons. \.øu A\as\{a h cL ~"thora\1e Subject: Report of Sundry Well Operations for 3S-15 (APD # 202-254) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation and perforation operations on the Kuparuk well 3S-15. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, pt. 1t1~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad r'\ f'"', ! (~'\ ~, f\ ! lJ r< ~ ~,~~/ ~ l \\J. \ , l_. 1. Operations Performed: ) STATE OF ALASKA ) R.E:,CE\VED ALASKA OIL AND GAS CONSERVATION COMMISSION '" '2005 REPORT OF SUNDRY WELL OPERATIONSJAN 12 Stimulate 0 A't)\$\í.~ em .8lt~P.i[$ Cons[!j.Qmm'ssu~n Waiver 0 Time EA'ttlhæo[] D Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Re-enter Suspended Well 5. Permit to Drill Number: 202-254 6. API Number: 50-103-20444-00 Plug Perforations 0 Perforate New Pool 0 Perforate 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510 7. KB Elevation (ft): RKB 25' 8. Property Designation: ADL 380106 / ALK 4623 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: 4. Current Well Status: Development _ 0 Stratigraphic 0 Service Exploratory 0 o 9. Well Name and Number: 3S-15 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 8420' feet true vertical 6209' feet measured 8212' feet true vertical 6004' feet Length Size MD 108' 16" 108' 3533' 9-5/8" 3561' 8378' 7" 8404' Plugs (measured) Junk (measured) Burst Collapse TVD 108' 2609' 6193' Measured depth: 8103'-8118' true vertical depth: 5897'-5911' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7807' MD. Packers & SSSV (type & measured depth) Bake SAB-3 pkr @ 7776' Cameo 'OS' nipple @ 496' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8103'-8118' C-4 sand frac, pumped 57601#, 16/20 carbolite Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation SI Subsequent to operation 444 268 38 283 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney #-~ Title Phone Wells Group Team Leader /, . / 907 -263-457 4 Date / /14/ d5 Prepared bv Sharon Allsup-Drake 263-4612 ,RBDMS 8Ft JAN 1. :} 2005 Submit Original Only 'I ¡ i-. Form 10-404 Revised 04/2004 \ \. \,_",,'~ ~ '..:.J TUBING (0-7807, 00:3,500, 10:2,992) SURFACE (0-3561 , 00:9.625, \M:40.00) RODUCTION (0-8404, 00:7,000, \M:26.00) SLEEVE-G (7713-7714, 00:4.520) PBR (7759-7761, 00:5.870) NIP (7800-7801, 00:4.490) Perf (8103-8118) FRAC (8103-8118) SHOE (8402-8403. 00:7.000) ) ConocoPhillips Alaska,lnc.. ) KRU 35-15 Well Type: PROD Angle ~ TS: 10 deg ~ 8102 Orig Completion: 1/25/2003 Angle ~ TO: 9 deg ~ 8420 Last W/O: Rev Reason: Correct CSG & TBG tops Ref Log Date: Last Update: 12/28/2004 TO: Size Top Bottom TVD Wt Grade Thread 16.000 0 108 108 62.50 H-40 WELD 9.625 0 3561 2609 40.00 L-80 BTCM 7.000 0 8404 6193 26.00 L-80 BTCM API: 501032044400 SSSV Type: NIPPLE Annular Fluid: Description CONDUCTOR SURFACE PRODUCTION Tubing String - Size 3.500 24.59' RKB 8212 10/4/2004 Interval 8103 - 8118 TVD 5897 - 5911 Zone C-4 Status Ft SPF Date Type Comment 15 6 3/4/2003 IPERF 2,5" HSD, 60 deg phase, 1000 psi uUnderbalanced Comment C-4 SAND FRAC, PUMPED 57601# 16/20 CARBO LITE, TSO @ 9 ppg ON FORMATION V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 4/3/2004 DMY 1.5 RK 0.000 0 4/4/2004 Stimulations & Treatments Interval Date Type 8103 - 8118 12/24/2004 FRAC Gas LifíMandrelsfValves St MD TVD Man Man Type Mfr 1 3527 2590 CAMCO KBUG-M 2 5513 3819 CAMCO KBUG-M 3 6765 4675 CAMCO KBUG-M 4 7429 5249 CAMCO KBUG-M 5 7662 5466 CAMCO MMG Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 25 25 HANGER 496 495 NIP 7713 5515 SLEEVE-C Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' NIPPLE WINO GO PROFILE BAKER CMU SLIDING SLEEVE WINO GO PROFILE 2.812" - CLOSED 9/6/2004 PBR BAKER PBRlSBR 80-40 PBR SEAL ASSEMBLY ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE PACKER BAKER SAB-3 PACKER EXTENSION BAKER MILL OUT EXTENSION NIP CAMCO '0' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER SHEAR OUT SEAT SHOE 7" WEATHERFORD SURE-SEAL MODEL 303 FLOAT SHOE ID 3.500 2.875 2.812 7759 5559 7775 5575 7776 5576 7781 5580 7800 5599 7807 5606 8402 6191 Generàl·. Notes Date I Note 7/22/2004 MITIA 3000 psi PASSED 3.000 3.000 3.250 3.720 2.750 2.950 6.161 ) 3S-15 Well Events Summary ) Date Summary 11/06/04 PERFORMED SRT FROM 1/2 BPM UP TO 5 BPM. THEN PUMPED 60 DEGREE SLICK SEAWATER @ A MAX RATE OF 10.8 BPM & MAX WHTP OF 3850 PSI. PUMPED A TOTAL OF 713 BBLS OF COLD SW & FREEZE PROTECTED WELL WI MEOH/DIESEL DOWN TO 2800' RKB. RECORDED PRESS/TEMP AT 8083' DURING SRT AND HPBD. 11/27/04 PERFORATE THE INTERVAL 8103-8113' USING 2.5" HSD GUNS LOADED 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. CHARGES WERE 2506 POWERFLOW HMX. API PENETRATION = 4.8"; ENTRANCE HOLE = 0.66". WELL SHUT IN AND FREEZE PROTECTED TO SURFACE WHEN FIRED. 12/14/04 COMPANION VLV LEAKING AT STEM. NEEDS TO BE REPLACED. COULD NOT MAKE TAG. 12/15/04 HEAT FRAC TANK WATER IN PREP FOR FRAC [Frac-Refrac] 12/24/04 DATAFRAC AND FRAC TREATMENT INTO THE PALM C-4 ZONE WITH 30# XL GEL AND 16/20 CARBOLlTE. Screen out - 59747# total proppant pumped with 57601# 9 ppa 104% design placed in perfs 2146# left in well. Proppant top approximately 7420' 67 bbls of flush including 38 bbl diesel. 12/29/04 CLEANED OUT FRAC SAND TO 8217' CTD USING A 1.75" JET SWIRL NZL. 100% RETURNS WITH HEAVY SAND TO TANKS. WASHED MANDRELS WHILE POOH. PUMPED 680 BBLS DIESEL, 100 BBLS DIESEL GEL. FREEZE PROTECTED WITH DIESEL. [FCO] 12/30104 TAGGED FILL @ 8120' RKB EST. 2' OF RAT HOLE. OPENED CMU @ 7713' RKB. SET JET PUMP IN CMU @ 7713' RKB (2.81 CS LOCK-3" R.C. JET PUMP SER. 1120 AND HAS A 9-B RATION #9-NOZZLE-#10 THROAT 1155" OAL). PERFORMED INJECTIVITY TEST DOWN IA THROUGH JET PUMP @ 1/2 BPM FOR 6 BBLS. ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocJ'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 June 3, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3S-15 (APD # 202-254) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3S-15. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )Á, M~~ M. Mooney Wells Group Team Leader CPAI Drilling and Welfs MM/skad RECEIVED JUN '1 fi ?004 NaMa ()jJ & Gas Cons. "^_..... . ~ VVI,n"_n 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhil lips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 25' 8. Property Designation: ADL 3801061 ALK 4623 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8420' feet true vertical 6209' feet measured 8126' feet true vertical 5919' feet Length Size MD 108' 16" 108' 3533' 9-5/8" 3561' 8378' 7" 8404' ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell D Pull Tubing D Operat. ShutdownD Stimulate 0 Waiver D Other o o o Plug Perforations 0 Perforate New Pool 0 Perforate D 4. Current Well Status: Development _ 0 Stratigraphic 0 Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 202-254 I 6. API Number: 50-103-20444-00 Exploratory Service o o 9. Well Name and Number: 3S-15 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2609' 6193' RECEIVED JUN 1 F; (004 AD.a Oil & Gas Con ' . AndD~ Commß88ign Measured depth: 8103'-8118' true vertical depth: 5897'-5911' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7807' MD. Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 7776' SSSV= nipple = 496' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8103'-8118' Treatment descriptions including volumes used and final pressure: fullbore 720 bbls diesel high pressure breakdown 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney k J/ tff'j Title Phone Wells Group Team Leader ,/ "7 / Date ([,y 3/ Ó~ Prepared bv Sharon Allsup-Drake 263-4612 Form 10-404 Revised 04/2004 ßf¡l ø1\6. Submit Original Only TUBING (24-7807, 00:3.500, 10:2.992) ROOUCTlON (26-8404, 00:7.000, Wt:26.00) SLEEVE-O (7713-7714, 00:4.520) PBR (7759-7761, 00:5.870) NIP (7800-7801, 00:4.490) Perf (8103-8118) SHOE (8402-8403, 00:7.000) ) Co n()êoPhilnpsAI~sk;a""lne.. I ~ L l ] - ~ ]~I"-~"" I <, '-" ,'.":;'::" i.:;' ,~~ '" ---::1..'. ~ . -:::.. .1.:: .. . Î ]1' "~','" ...:"~ J j .~~, I \ ~,' Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'DS' NIPPLE WINO GO PROFILE BAKER CMU SLIDING SLEEVE WINO GO PROFILE 2.812" - OPENED 4/4/2004 PUMP JET PUMP set 4/4/2004 PBR BAKER PBR/SBR 80-40 PBR SEAL ASSEMBLY ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE PACKER BAKER SAB-3 PACKER EXTENSION BAKER MILL OUT EXTENSION NIP CAMCO 'D' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER SHEAR OUT SEAT SHOE 7" WEATHERFORD SURE-SEAL MODEL 303 FLOAT SHOE . API: 501032044400 SSSV Type: NIPPLE Annular Fluid: Reference Loç¡: 24.59' RKB Last Taç¡: 8126 Last Taç¡ Date: 2/21/2004 Casil;g . String ~,AlL, STRI NGS Description PRODUCTION SURFACE CONDUCTOR Interval 8103 - 8118 TVD 5897 - 5911 Gas Lift MandrelslValves St MD TVD Man Man Type Mfr 1 3527 2590 CAMCO KBUG-M 2 5513 3819 CAMCO KBUG-M 3 6765 4675 CAMCO KBUG-M 4 7429 5249 CAMCO KBUG-M 5 7662 5466 CAMeO MMG Other (plugs, equip., etc.)- JEWELRY Depth TVD Type 25 25 HANGER 496 495 NIP 7713 5515 SLEEVE-O 7713 7759 7775 7776 7781 7800 7807 8402 5515 5559 5575 5576 5580 5599 5606 6191 ) KRU 35-15 Well Type: PROD Angle cæ TS: 10 deg cæ 8102 Orig Completion: 1/25/2003 Angle cæ TD: 9 deg cæ 8420 Last W/O: Rev Reason: GLV design, Open Sleeve, set pump Ref Log Date: Last Update: 4/6/2004 TD: 8420 ftKB Max Hole Anç¡le: 58 deç¡ @ 2543 Size Top Bottom TVD Wt Grade Thread 7.000 26 8404 6193 26.00 L-80 BTCM 9.625 28 3561 2609 40.00 L-80 BTCM 16.000 28 108 108 62.50 H-40 WELD TVD Grade Thread 5606 L-80 EUE8RD Zone Status Ft SPF Date Type Comment C-4 15 6 3/4/2003 IPERF 2.5" HSD, 60 deg phase, 1000 psi uUnderbalanced VMfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 4/3/2004 DMY 1.5 RK 0.000 0 4/4/2004 ID 3.500 2.875 2.812 0.000 3.000 3.000 3.250 3.720 2.750 2.950 6.161 ') 3S-15 Well Events Summary ) Date Summary OS/22/04 PUMP 720 BBLS DIESEL TO BREAK WELL DOWN AND FLUSH FORMATIOND [HPBD] ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 12,2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3S-15 (APD # 202-254) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent conversion from gas lift to surface powered jet pump lift on the Kuparuk weIl3S-15. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, JU dtl1JW5 M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED MAY 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL 1. Operations Performed: ') ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Abandon REPORT OF SUNDRY WELL OPERATIONS o Suspend 0 Operation Shutdown 0 o Repair Well D Plug Perforations 0 o Pull Tubing 0 Perforate New Pool D Other 0 Variance o Annular Disp. D o o Perforate 0 Stimulate 0 Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 25' Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 202-2541 6. API Number: 50-103-20444-00 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory Service o D 9. Well Name and Number: 3S-15 8. Property Designation: ADL 3801061 ALK 4623 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8420' feet true vertical 6209' feet measured 8126' feet true vertical 5919' feet Length Size MD 108' 1611 108' 3536' 9-5/811 3561' 8379' 711 8404' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2609' 6193' Measured depth: 8103'-8118' RECEIVED MAY 1 4 2004 true vertical depth: 5897'-5911' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7807' MD. Alaska Oil & Gas Cons. CorTimission Anchorage Packers & SSSV (type & measured depth) Baker SA B-3 pkr packer @ 7776' SSSV= NIP SSSV= 496' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation not available not available not available Subsequent to operation not available not available not available 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Marie McConnell @ 659-7224 Mike Mooney JJl,¡{~ Title Phone Wells Group Team Leader I / Date 6{ , 3 I () f Preoared bv Sharon Al/suo·Drake 263-4612 :~~~ Bft MAYA 4 1.~~~ nQ'GIf\LAJ Form 10-404 Revised 2/2003 · SUBMIT IN DUPLICATE ') Conoêo';PhillipsAla,ska".,lnfJ~ 3S-15 ' TUBING (24-7807, 00:3.500, 10:2.992) ROOUCTION (26-8404, 00:7.000, Wt:26.00) SLEEVE-O (7713-7714, 00:4.520) PBR (7759-7761, 00:5.870) NIP (7800-7801, 00:4.490) Perf (8103-8118) SHOE (8402-8403, 00:7.000) ~l>'_ ~ .'I,C"-'¡I - ¡~ ., ],. ]ftl rr_ ['>'1 .1 Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'DS' NIPPLE WINO GO PROFILE BAKER CMU SLIDING SLEEVE WINO GO PROFILE 2.812" - OPENED 4/4/2004 PUMP JET PUMP set 4/4/2004 PBR BAKER PBR/SBR 80-40 PBR SEAL ASSEMBLY ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE PACKER BAKER SAB-3 PACKER EXTENSION BAKER MILL OUT EXTENSION NIP CAMeO 'D' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER SHEAR OUT SEAT SHOE 7" WEATHERFORD SURE-SEAL MODEL 303 FLOAT SHOE API: 501032044400 SSSV Type: NIPPLE Annular Fluid: Reference Log: 24.59' RKB Last Tag: 8126 Last Tag Date: 2/21/2004 CasingStrihg ~ALL STRINGS Description PRODUCTION SURFACE CONDUCTOR TubingString.~TUBING SI, Z, e 1 Top 3.500 24 Perforätlons Summai"ÿ Interval TVD 8103-8118 5897-5911 Gäs Lift MandrelslValves St MD TVD Man Man Type Mfr 1 3527 2590 CAMCO KBUG-M 2 5513 3819 CAMeO KBUG-M 3 6765 4675 CAMeo KBUG-M 4 7429 5249 CAMeo KBUG-M 5 7662 5466 CAMeo MMG Other (plugs,equip;, etc;) -JEWELRY Depth TVD Type 25 25 HANGER 496 495 NIP 7713 5515 SLEEVE-O 7713 7759 7775 7776 7781 7800 7807 8402 5515 5559 5575 5576 5580 5599 5606 6191 ~ ) KRU 38-15 Well Type: PROD Angle ~ TS: 10 deg cæ 8102 Orig Completion: 1/25/2003 Angle ~ TD: 9 deg cæ 8420 Last W/O: Rev Reason: GLV design, Open Sleeve, set pump Ref Log Date: Last Update: 4/6/2004 TD: 8420 ftKB Max Hole Angle: 58 deg ~ 2543 Size Top Bottom TVD Wt Grade Thread 7.000 26 8404 6193 26.00 L-80 BTCM 9.625 28 3561 2609 40.00 L-80 BTCM 16.000 28 108 108 62.50 H-40 WELD Bottom TVD Wt Grade Thread 7807 5606 9.30 L-80 EUE8RD Zone Status Ft SPF Date Type Comment C-4 15 6 3/4/2003 IPERF 2.5" HSD, 60 deg phase, 1000 psi uUnderbalanced VMfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 11/13/2003 DMY 1.0 BK 0.000 0 4/3/2004 DMY 1.5 RK 0.000 0 4/4/2004 ID 3.500 2.875 2.812 0.000 3.000 3.000 3.250 3.720 2.750 2.950 6.161 ') 3S-15 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary IConverted from gas lifted to surface powered jet pump lift as follows: 4/3/2004IPulled GLVs and started replacement with dummy valves 4/4/2004 Loaded IA with SW and diesel cap. Completed dummy valve installation. MITIA to 3000 psi passed as follows: Pre T/IA/OA = 1500/2500/300 psi, Initial T/IA/OA = 1500/3000/350,15 minute T/IA/OA = 1500/3000/300, 30 minute T/IA/OA = 1450/3000/300 psi. Opened Sliding sleeve @ 7713'. Set Jet Pump @ 77131. RE: 3~~} 5 upcoming work I ') ") J dOd-dS~ Subject: RE: 3S-15 upcoming work From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 30 Mar 2004 14:39:42 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Thanks Tom. We will perform the MITIA and file the 10-404 once the well Îs converted to surface powered jet pump Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 30, 2004 2:26 PM To: NSK Problem Well Supv Cc: Allsup-Drake, Sharon K; CPF3 Prod Engrs; Jim Regg Subject: Re: 3S-15 upcoming work Marie, A 403 is not required. However, an MIT IA should be conducted in conjunction with converting the well to jet pump. The MIT results may be submitted with the 404. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, The well is 3S-15 (202-254). It is currently being gas lifted. A rig workover is not required to convert to surface powered jet pump. There is a sliding sleeve above the packer. The work can be completed by Slickline. The ,GLMs would be DV'd off, the sleeve opened, and a jet pump installed in the sleeve profile. Power fluid (water injection water) would be injected down the IA and commingled in the jet pump with produced fluids for production up the tubing. Should a 10-403 be filed to pre-approve or is just the 10-404 notification of conversion required? Thanks, Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: Thoma s Ma unde r [~.9.:.~..:h.~".?_:._tc:?~-:0._~.9.:.~.!1.:ª-.~E~~9:.?:.~~!.?.:..:_.~..~.9:.!:.§::_:...?:..~_.:..~_~.] Sent: Tuesday, March 30, 2004 1:42 PM To: Allsup-Drake, Sharon K Cc: CPF3 Prod Engrs; NSK Problem Well Supv Subject: Re: 3S-15 upcoming work Sharon and CPF-3 Engineers, How will this be accomplished?? Is the equipment already in the well or will a workover be required?? 403s are not generally required for Kuparuk pool production wells, however a 404 should be submitted to not the change in artificial lift method. I look forward to your reply. Tom Maunder, PE AOGCC 10f2 3/30/20042:50 PM RE: 38-15 upcoming work ,~ iJ> ¡ 20f2 ') ) Allsup-Drake, Sharon K wrote: Tom - I am wondering if we need to submit a sundry concerning our intention to change from gas lift to jet pump on a certain well. Does this warrant submitting any paperwork? Thanks, Sharon office phone: 263-4612 fax: 2 65 - 6224 3/30/2004 2:50 PM ) Conocri'Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ) J?~CJ2/J i . {".' VE:D 1'ilkoO¡l,; 0 t 2003 ~t Gas Ca ..¡,¡~, Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. :;;; ~/ / MJ~ ConocoPhillips Problem Well Supervisor Attachment :t:.\- '\ ~ r-<J~ c<. ~,~~ ~~ ~''-Q.~~\-' +0 cr k \ \ 'o'->...c-~" cA-~, ~c:el ~~ '::><.XL<!:. "'<;,.~ù \ \ '-I ~<l. "^-«. "-~~ -\ð S""~. À \ \ o~-\-~ "T()~" ~-\-"'-S ~~ \::>Qt"'1 ~Q.G\ +~Cê. Sû~~. ~ 0 .Çù ,-\- ""'C?-..' a.. c..-\ \ 0 '" f".,Q..ct.. ~<J..' '{ ß)!/rr?I~Á-\J-S · GonocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume Sacks Name PTO# Type ft 88lS Cement 38-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 38-15 2022540 Prod 8 0.8 4.8 38-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 38-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 ) ) '7-07- .. ?. ~<f I \ (pqCS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tll Avenue, Suite 100 Anchorage, Alaska June 03, 2003 RE: MWD Formation Evaluation Logs 3S-15, AK-MW-30003 1 LDWG formatted Disc with verification listing. ~I#: 50-103-20444-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVE,[) l~d:Of~]e Date: JUL 24 200,3 AJaaka Or),~ Gas c{¡{¡;::. C:;omm¡~~n Note: This Data Replaces Any Previous Data For WeIl3S-15. ') ) aO¡J-d$lt- l/lp,-/ 5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Pu1chorage,Alaska April 18,2003 RE: MWD Formation Evaluation Logs 3S-15, AI(-MW-30003 1 LDWG formatted Disc with verification listing. API#: 50-103-20444-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~~ RECEIVED APR 2 9 2003 Alaska Oii & G as "A_c., r. A.. 'Nfl\JI. ~mmi.a....:- a"lUchontge -··..~n ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of SelVice Well Oil [2] Gas D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned D SelVice D ~~w:~~:;t:~~t~tt~~'!:~~?~'~,:: (,y '~"'~~'''''''Ú '~""~R',;',:: , ~i~', ;.1,,: ,.I; .,~,,~.. ":/¿Jt ';'. ,~{" 'S'r.', ,.. ' ¡;ri'''''\"" " ~~,'~;::~;;~~,;,:~;;'::",'~,;:1Þ (ASP: 476169,5993892) - ." -:;'C;~~:::t0~~r) . -'t'. . ',i" ',' ¡I! , 7. '::>.t>5~ ~,' ~~-:":-I \Æ:' ,-ud/ t' '~~"t".~I\"::=Î 7. Permit Number 202-254 I 8. API Number 50-1 03-20444 9. Unit or Lease Name 2524' FNL, 1091' FEL, Sec. 18, T12N, R8E, UM At Top Producing IntelVal 1599'FSL, 929' FWL, Sec. 7, T12N, R8E, UM At Total Depth 1638' FSL, 894' FWL, Sec. 7, T12N, R8E, UM (ASP: 473364, 5998063) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 28 feet ADL 380106 ALK 4623 12. Date Spudded I' 13. Date T.D. Reached I 14. Date Comp., Susp. Or Ab~~h 3~' 15. Water Depth, if offshore January 10,2003 January 17, 2003 ~~nl)~ry 2~, 20U;j~ I ~ N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional SUlVey 20. epth where SSSV set 8420' MD I 6209' TVD 8235' MD I 6026' TVD YES [2] No D Land Nipple @ 496' Kuparuk River Unit 10. Well Number (ASP: 473398, 5998023) 3S-15 11. Field and Pool Kuparuk River Oil Pool Kuparuk River Field 16. No. of Completions 21. Thickness of Permafrost 1700' MD 22. Type Electric or Other Logs Run GR/Res/Dens/Neut, CBL w/SCMT 23. CASING SIZE WT. PER FT. 16" x 30" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3561' Surface 8403' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 102 sx Arctic Crete 8.5" 540 sx AS IIIL, 316 sx LiteCrete 59 bbls Class G w/GasBlok 12.25" 24. Perforations open to Production (MD + TVD of Top and Bottom and intelVal, size and number) 3.5" TUBING RECORD DEPTH SET (MD) 7807' PACKER SET (MD) 7776' 25. SIZE 8103' - 8118' MD 5897' - 5911' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 6, 2003 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 4/15/2003 4.1 hours Test Period> 266 1485 0 100 1879 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 243 psi not available 24-Hour Rate> 1596 8916 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RECEIVED APR 1 7 Z003 MDMs SFL APR 3 0 2003 Alaska Oil & Gas Cons. Commission Anchorage ~~ Form 10-407 Rev. 7-1-80 CONÒR\ G]~Äl Submit in duplicate 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top Kuparuk Base Kuparuk 8102' 8118' 5896' 5911' Annulus left open - freeze protected with diesel. RECEIVED APR 1 7 7003 Alaska Oil & Gas Cons. Commission Anohorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 Signed ~ ~tle R. Thomas Kuparuk Drillinq Team Leader Date '4 10,3/0 :) Prepared by Sharon Allsup-Drake 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 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 ORIGINAL ) ') NOTE: ACCEPTED RIG @ 08:00 HRS 1/10103 RIH with 1 Std DP, Function Tested Divertor System & Ck OK, NOTE: Chuck Scheave with AOGCC Waived Witnessing of Test PU 2 Stab's, 121/4" Bit & UBHO Sub & Bring to Rig Floor PU 3-6 3/4 Flex Dc's & Stand Back, PU & MU BHA #1 & Orient RU HES Slickline for Gyro Est Circ & Tested Surface Mud Lines to 3,500 Psi, Tested MWD, RIH & Tagged Up @ 86', Cleaned Out to Btm @ 108' Ball Mill Down, Blow Down Top Drive and Changed Out Lower Shaft on Bucket Elevator Spud Well & Drill 12 1/4" Hole from 108' to 160' MD, ART .75 Hrs. 10K WOB, 40 RPM's, 352 Gpm's @ 650 Psi, ROT Wt 40K, PU 40K, Own Wt 40K, Off Btm Torque 1,000 Ft#'s, On Btm 1,500 Ft#'s Drill 12 1/4" Hole from 160' to 183', ART 1/4 Hr, circ for Gyro RIH with Sperry Sun Gyro on HES Slickline, Gyro @ 183' Drill 12 1/4" Hole from 183' to 270', AST 1 1/4 Hr, Circ for Gyro RIH with Sperry Sun Gyro on HES Slickline, Gyro @ 270' Drill 12 1/4" Hole Per Directional Plan from 270' to 998' MOl 983' TVD, ART 2 1/2 Hrs, AST 2 3/4 Hrs, 35K WOB, 90 Rpm's, 146 SPM, 427 Gpm's with 1,045 Psi Off Btm Press, 1,300 Psi On Btm, Off Btm Torque 1 k Ft#'s, On Btm 6K Ft#'s, Rot Wt 72K, Pu Wt 72K, Own Wt 70K, RD HES Wireline & Sperry Sun Gyro 12.00 DRILL DRLG SURFAC Drill 12 1/4" Hole Per Directional Plan from 998' to 1,946' MDI 1,732' TVD, ART 2114 Hrs, AST 7 3/4 Hrs, 40K WOB, 70 Rpm's, 140 SPM, 400 Gpm's with 1,070 Psi Off Btm Press, 1,250 Psi On Btm, Off Btm Torque 3k Ft#'s, On Btm 6K Ft#'s, Rot Wt 80K, Pu Wt 83K, Dwn Wt 65K, At 1,600' Began Adding Barafiber at 1-2 ppb Per Mud Program *Richard Roy, Nabors Pitwatcher was Medi-Vac to Anchorage Due to Chest Pains per KUP PA 12.00 DRILL DRLG SURFAC Drill 12 1/4" Hole Per Directional Plan from 1,946' to 3,278' MOl 2,456' TVD, ART 6 3/4 Hrs, AST 3/4 Hrs, 40-55K WOB, 100 Rpm's, 203 SPM, 590 Gpm's with 2,300 Psi Off Btm Press, 2,500 Psi On Btm, Off Btm Torque 5k Ft#'s, On Btm 9,500K Ft#'s, Rot Wt 80K, Pu Wt 90K, Own Wt 70K, Pumped 2 Baralift Sweeps at .1 ppb @ 2,422' & 1 at .15 ppb at 2,994' with Minimal Cuttings Increase 3.00 DRILL DRLG SURFAC Drill 12 1/4" Hole Per Directional Plan from 3,278' to 3,572' MOl 2,615' TVD, (95/8" Csg Pt.) ART 1 1/2 Hrs, 45-55K WOB, 100 Rpm's, 205 SPM, 600 Gpm's with 2,350 Psi Off Btm Press, 2,700 Psi On Btm, Off Btm Torque 5k Ft#'s, On Btm 9,500K Ft#'s, Rot Wt 83K, Pu Wt 98K, Own Wt 72K, Ave BGG 40 Units Legal Well Name: 3S-15 Common Well Name: 3S-15 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES Date Hours.' Code Sub Phase Code 1/1 0/2003 00:00 - 02:00 2.00 MOVE MOVE MOVE 02:00 - 02:30 0.50 MOVE RURD MOVE 02:30 - 03:30 1.00 MOVE RURD MOVE 03:30 - 04:30 1.00 MOVE MOVE MOVE 04:30 - 05:30 1.00 MOVE MOVE MOVE 05:30 - 06:00 0.50 RIGMNT RGRP MOVE 06:00 - 07:00 1.00 MOVE MOVE MOVE 07:00 - 08:00 1.00 MOVE MOVE MOVE 08:00 - 10:00 2.00 WELCTL NUND RIGUP 10:00 - 10:30 0.50 WELCTL OTHR SURFAC 10:30 - 11 :00 0.50 DRILL PULD SURFAC 11 :00 - 14:30 3.50 DRILL TRIP SURFAC 14:30 - 16:00 1.50 LOG RURD SURFAC 16:00 - 18:30 2.50 DRILL OTHR SURFAC 18:30 - 23:00 4.50 RIGMNT RGRP SURFAC 23:00 - 00:00 1.00 DRILL DRLG SURFAC 1/11/2003 00:00 - 00:30 0.50 DRILL DRLG SURFAC 00:30 - 02:00 1.50 DRILL SURV SURFAC 02:00 - 03:30 1.50 DRILL DRLG SURFAC 03:30 - 04:00 O.sp DRILL SURV SURFAC 04:00 - 12:00 8.00 DRILL DRLG SURFAC 12:00 - 00:00 1/12/2003 00:00 - 12:00 12:00 - 15:00 Start: 1/10/2003 Rig Release: 1/25/2003 Rig Number: Land Spud Date: 1/10/2003 End: Group: Pulled Mud Pits & Moved Rig Off 3S-1 0 and Moved Down Pad to 3S-15 Set Extra Divertor on 3S-16 for Next Move Lay Mats & Herculite over Cellar on 3S-15, Set in Cellar Area, Csg & Tbg Spool, DSA, Tree & Adapter Flange, Set In Stump for Divertor Spot Rig over Well & Level Same Spot Mud Pits & Start Hooking Up Service Lines Repaired Truck Used to Move Ball Mill Spot Ball Mill, Take Water on in Pits, Started NU 21 1/4" Divertor @ 07:00 Hrs, Changed Out Btm air Boot on Top Dresser Sleeve, Note: Divertor & Speed Head was Set on Well Prior to Rig Moving Onto Well Spot Inj Tank & Inj Skid, Berm Tank Made Up 16" Divertor Line to 21 1/4" Divertor, Cleaned Cellar Area Printed: 1/31/2003 3:08:31 PM ) ') GondcoRhillipsAlas.ka ,Operati()ns.,· S,l¡J,ltImøry ..·RE!por~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-15 38-15 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 1/1 0/2003 Rig Release: 1/25/2003 Rig Number: Land Spud Date: 1/10/2003 End: Group: 8úþ, Cddë 2.00 DRILL CIRC SURFAC Pumped 2-40 bbl Sweeps with .15 ppb Baralift, 1st Sweep had 50% Improvement in Cuttings, After Btms up, Pumped 2nd Sweep had Minimal Increase in Cuttings, Circ Hole Clean, Circ @ 600 Gpm, 2,350 Psi and 100 Rpm's Rotary, Sweeps Came Up on Calc Strokes, Monitored Well-Static POOH Wet, No Problems POOH, Ave 5-10K Drag, POOH to BHA, Monitored well at BHA-Static, SLM No Corr. POOH & Stood Back HWDP & Flex Dc's, LD Stab, UBHO Sub, NMDC, MM & Bit, Cleared Rig Floor Began RU GBR Csg Tools, Changed Out Elevator Bails & MU Franks Fill-Up Tool Fin RU GBR Csg Tools & RU stabbing board. Held prejob safety and opts meeting with rig crew and casers. MU 9 5/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 85 Jts of 9 5/8" Csg, (Total of 87 Jts Ran 3,530.41') TIH with No Problems, Landed Csg in Head - Landed Csg wI FS @ 3,561', FC @ 3,472'. Ran 14 Bow Spring Centralizers Per Well Program 0.50 CEMENT PULD SURFAC LD fill-up tool and MU cement head. 3.75 CEMENTCIRC SURFAC Established circ @ 3.0 bpm 1420 psi - staged pumps up to 8 bpm and conditioned mud. Lowered wt fl 9.6 ppg tJ 9.2 ppg, FV f/166 to 62, PV fl 42 tJ 31, YP fl 38 tJ 22. Reciprocated pipe with full returns throughout, PUW=125k SOW=95k. Final rate 8.0 bpm 1525 psi - total of 1290 bbls pumped, last 100 bbls with nutplug marker. PJSM. 1.50 CEMENT SEOT SURFAC Line up to cementers and pumped 5 bbls of CW. Tested lines to 3000 psi - pumped additional 45 bbls of CW 100. Dropped bottom plug and pumped 49 bbls of 10.5 ppg MudPUSH XL spacer wI dye marker, 410 bbls of 10.7 ppg ASlite lead slurry @ 8.2 ppg 1950 psi and 125 bbls of 12.0 ppg Lite CRETE tail slurry @ 8.2 ppg 11650 psi. landed casing with 90 bbls of tail pumped. 1.00 CEMENT DISP SURFAC Dropped top plug and displaced with 20 bbls of FW from cementers - switched to rig pumps and displaced with mud @ 8 bpm 1552 - 732 psi untill 50 bbls of tail around shoe - reduced rate to 6 bpm 1585 - 650 psi, slowed to 4 bpm I 510 psi -last 5 bbls pumped [242.5 bbls total]. Bumped plugs to 1100 psi - floats held - had full returns throughout with 275 bbls of 10.7 ppg cement returns to surface CIP @ 1335 hrs. Rig down cement lines - LD cement head. LD cement head - flush surface stack and flowline - LD landing jnt. LD casing elevators and long bails - remove tools from rig floor. Hang short (drilling) bails on Top Drive. Nipple down 20" Divertor system. Install FMC Gen V casing head and tubing spool, tested M/M seal to 1000 psi. Nipple up 13 5/8", 5000 psi BOPE. Install test plug and joint - RU to test BOPE. Test BOPE 250/5000 psi. AOGCC Inspector Chuck Scheve on location. Continue testing BOPE: Tested choke, kill, manifold and surface safety valves, pipe & blind rams 250 I 5000 psi. Tested upper rams with 7" test joint, annular 250 I 3500 psi. Chuck Scheve witnessed and approved tests. RD test equipment and blow down lines. 1.00 DRILL OTHR SURFAC Install wear bushing, RD stabbing board and install mousehole. 1.00 DRILL PULD SURFAC RIH, picking up 5" drill pipe (24 joints). 1/12/2003 15:00 - 17:00 17:00 - 20:30 3.50 DRILL TRIP SURFAC 20:30 - 23:00 2.50 DRILL TRIP SURFAC 23:00 - 00:00 1.00 CASE RURD SURFAC 1/13/2003 00:00 - 01 :30 1.50 CASE RURD SURFAC 01 :30 - 02:00 0.50 CASE SFTY SURFAC 02:00 - 07: 15 5.25 CASE RUNC SURFAC 07:15 - 07:45 07:45 - 11 :30 11 :30 - 13:00 13:00 - 14:00 14:00 - 16:00 2.00 CASE RURD SURFAC 16:00 - 17:30 1.50 CASE NUND SURFAC 17:30 - 18:30 1.00 CASE NUND SURFAC 18:30 - 21 :00 2.50 CASE NUND SURFAC 21 :00 - 22:00 1.00 WELCTL BOPE SURFAC 22:00 - 00:00 2.00 WELCTL BOPE SURFAC 1/14/2003 00:00 - 03:30 3.50 WELCTL BOPE SURFAC 03:30 - 04:30 04:30 - 05:30 Printed: 1/31/2003 3:08:31 PM ) ) ÇonoêoPhilliþsAlaskél ·Opørati()nsSUI'I1I'11ê1ry, .RC!port, ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-15 38-15 ROT - DRILLING n1268@conocophillips.com Nabors 7E8 ., ,Sub Hours Code Code Spud Date: 1/10/2003 End: Group: 8tart: 1/1 0/2003 Rig Release: 1/25/2003 Rig Number: Land Description of Opera.tions 1.00 RIGMNT RSRV SURFAC Service Top Drive and Drawworks. 0.50 DRILL OTHR SURFAC POH, stand back 8 stands in derrick. 5.00 DRILL TRIP SURFAC MU 81/2" BHA #2, Sperry Sun's Quad Combo W/Sonic & Acoustic Caliper Tool, Tested MWD,Held PJSM, Loaded Nuclear Source & RIH with HWDP to 954' PU 5" DP from Pipe Shed & RIH with BHA #2 to 1,400' Repaired Pipe Skate Cont TIH PU 5" DP, Tagged Up @ 3,435', (Float Collar @ 3,472') Cleaned Out to 3,462', (10' Above FC) Circ Btms Up for Csg Test Blow Down Top Drive, RU & Tested 9 5/8" Csg to 2,500 Psi for 30 Min & Charted Same Drilled Out Fit Collar, Med Cmt in Shoe Trac, Fit Shoe & 20' of New Form to 3,592' Circ Btms Up, Pumped Sweep & Displaced Hole with New 9.1 ppg LSND Mud Blow Down Top Drive, RU & Perform FIT to 1210 Psi for a 18.0 ppg EMW Drill 8 1/2 Hole from 3,592' to 3,710' MOl 2,71 0' TVD, (118'), ART 1 Hr, 20K WOB, 60 Rpm's, 550 Gpm's @ 1,750 Psi, Rot Wt 93K, PU Wt 118K, Down Wt 68K, Off Btm Torque 8K Ft#'s, On Btm 8,500 Ft#'s, Est PWD Base Line with 9.1 ppg Mud, Clean Hole with 9.6 ECD 1/14/2003 05:30 - 06:30 06:30 - 07:00 07:00 - 12:00 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 13:00 0.50 RIGMNT RGRP SURFAC 13:00 - 16:30 3.50 DRILL TRIP SURFAC 16:30 - 17:00 0.50 DRILL REAM SURFAC 17:00 - 17:30 0.50 DRILL CIRC SURFAC 17:30 - 18:30 1.00 CASE MIT SURFAC 18:30 - 20:00 1.50 CEMENT DSHO SURFAC 20:00 - 21 :30 1.50 DRILL CIRC SURFAC 21 :30 - 22:30 1.00 DRILL LOT SURFAC 22:30 - 00:00 1.50 DRILL DRLG PROD 1/15/2003 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 1/16/2003 00:00 - 01 :00 1.00 DRILL DRLG PROD 01 :00 - 02:00 1.00 RIGMNT RGRP PROD 02:00 - 12:00 10.00 DRILL DRLG PROD 12:00 - 18:00 6.00 DRILL DRLG PROD NOTE: Rig Camp went off High Line Power Due Heater Wire in Transformer Going Out, was on Generator Power for Hrs, Total Hrs Used 1 ,352 Hrs- Leaving 148 Hrs Left Drill 8 1/2" Hole Per Dir. Plan from 3,710' to 5,000' MD/3,485' TVD (1,290') 30-35K WOB, 110 Rpm's, 205 SPM, 600 Gpm's, Off Btm Press 2,200 Psi, On Btm Press 2,450 Psi, Off Btm Torque 9K Ft#'s, On Btm Torque 10K Ft#'s, Rot Wt 100K, Up Wt 140K, On Wt 80K, 9.3 ppg MW with 11.7 ECD, Ave Bgg 20 Units, Pumped Hi Vis Sweeps every 300' Drill 8 1/2" Hole Per Dir. Plan from 5,000' to 6,379 MD/4,388' TVD (1,379') 20K WOB, 110 Rpm's, 197 SPM, 575 Gpm's, Off Btm Press 2,680 Psi, On Btm Press 2,850 Psi, Off Btm Torque 11 K Ft#'s, On Btm Torque 12K Ft#'s, Rot Wt 120K, Up Wt 182K, On Wt 88K,Raised Mw from 9.3 to 10.1 ppg MW, ECD with 10.1 MW was 12.0 ppg ECD, Ave Bgg 35 Units, Max Gas 300 Units from C-40 Sand & Dropped Out, Pumped Weighted Hi Vis Sweeps every 300' to Clean Hole & Aid in Raising MW. NOTE: Completed Injecting on 3S-07 after Injecting 31,986 bbls including Final Freeze Protection, Moved Injection Line to 3S-18 & Tested Drill 8 1/2" Hole from 6,379' to 6,473', (94') ART 1/4 Hr, AST 1/4 Hr" #1 Pump Went Down Replaced 2 Swabs in #1 Mud Pump, Circ & Worked Pipe @ 105 SPM @ 910 Psi Drill Per Dir. Plan from 6,473' to 7,480' MD/5,297' TVD, (1,007') ART 4 1/4 Hrs, AST 1 1/4 Hrs 20K WOB, 105 Rpm's, 184 Spm 537 Gpm's with 2,715 Psi Off Btm Press & 3,025 Psi On Btm Press, Off Btm Torque 14.5K Ft#'s & On Btm Torque 15K Ft#'s, Rot Wt 134K, PU Wt 225K, On Wt 98K, 10.8 Mw In with 12.7 ECD, Ave BGG 20-50 Units Drill Per Dir Plan from 7,480' to 7,997' MD/5,792' TVD, (517') ART 3 Printed: 1/31/2003 3:08:31 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') QonQcoPhillipsAI(:1ska. , Qper¡:îtion$$ummary Report 3S-15 38-15 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Spud Date: 1/10/2003 End: Group: Start: 1/1 0/2003 Rig Release: 1/25/2003 Rig Number: Land Description qfOperations Date Sb< From-To Hours, Code' cò~e Phase· 1/16/2003 12:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 21 :15 21:15-22:30 22:30 - 23:00 23:00 - 00:00 1/17/2003 00:00 - 02:30 02:30 - 08:30 08:30 - 15:00 15:00 - 19:30 19:30 - 22:00 22:00 - 00:00 6.00 DRILL DRLG PROD 1.00 DRILL CIRC PROD 0.50 DRILL DRLG PROD 1.00 DRILL CIRC PROD 0.75 DRILL DRLG PROD 1.25 DRILL CIRC PROD 0.50 DRILL DRLG PROD 1.00 DRILL CIRC PROD 2.50 DRILL CIRC PROD 6.00 DRILL CIRC PROD 5.50 DRILL CIRC PROD 4.50 DRILL DRLG PROD 2.50 DRILL CIRC PROD 2.00 DRILL CIRC PROD 3/4 Hrs, AST 1 Hr, 20-30K WOB, 110 Rpm's, 170 Spm 500 Gpm's, Press Off Btm 2,420 Psi, On Btm 2,630 Psi, Torque Off Btm 15-17K, On Btm 13-16K Ft#'s, Rot Wt 150K, PU Wt 230K, On Wt 105K, 10.8 Mw In with 12.8 ECD Circ & Displace 10.8 ppg Mud in Hole with New 12.1 LSND Mud Drill from 7,997' to 8,020' MD/5,814' TVD, Flow Showed 16 bbl Loss, Shut Down Monitored Well, Regained 16 bbls Back, Well Out of Balance from Change Over or Possilbly Breathing, Circ Btms Up Max Gas 460 Units, Circ till 12.1 In & Out Thru Pill Pit While Active Sytem Being Weighted Up, Hole Appears to be Taking Fluid @ 10-15 BPH Drill from 8,020' to 8,091' MOl 5,884' TVD (71') ART 1/2 Hr, BGG Increased to 5,000 Units, PU Off Btm Circ Hole, Gas Dropped Out & Ave 180 units, at Btms Up Increased to 1,200 Units and dropped Out and Ave 200 Units with No Gas Cut Mud, Circ @ 430 Gpm's at 2,225 Psi and 13.28 ECD with 10-15 Bph losses, Began Adding LCM to Mud to Drill KUP "C" sand, Ave BGG from K Sand Ave 200-300 Units Drilled from 8,091' to 8,129' MOl 5,922' TVD, (48') ART 1/2 Hr, Drilling at Reduced Pump rate of 450 Gpm's & 2,300 Psi with a 13.1 ECD & 100'/Hr Rap to Drill KUP "C" Sand When Lost Returns Occured, Top of KUP "C" Projected @ 8,092' MD/5,889' TVD Slowed Pump to 300 Gpm's @ 1,315 Psi & Lost Complete Returns, Slowed Pump to 115 Gpm & 435 Psi & Regained Partial Circ, Circ & Rotated Pipe @ 75 Rpm's While Raising MW in Active Pits to 12.1 ppg, Gas Increased from 65 units to 250 Units, While Circ had 60% Returns, Lost a Total of 163 bbls as of 24:00 Hrs Circ Hole At A Reduced Rate Thru Pill Pit While Raising MW in Mud Pits to 12.1 ppg, Circ at 29 Spm-2 Bpm @ 300 Psi, 75 Rpm's and 16K Ft#'s Torque, Low Bgg 30 Units, High Bgg 500 Units, Ave 50 Units Bgg Circ with 75% returns @ 2 Bpm Began Pumping 12.1 ppg Mud While Mixing 10 ppb Lcm @ 29 Spm-2 Bpm @ 300 Psi w175% Returns, Increased Rate Up to 85 Spm-6 Bpm @ 1,050 Psi, Losses Decreased to 15% then Increased to 25%, Slowed Rate to 37 Spm-2 1/2 Bpm @ 350 Psi, Ave BGG 50 Units Began Circ Hole Thru Pill Pit Lowering MW to 11.8 ppg in Active System, Lowered MW in Mud Pits from 12.1 ppg to 11.8 ppg and Added 20 ppb LCM to Pits, While Circ Hole with 11.8 ppg Mud in & Out of Pill Pit Losses Stopped, Ave BGG 40 Units Staged Pumps Up from 2.5 Bpm to 8.5 Bpm @ 1,670 Psi and MWD Tool Ck Ok Drill81/2" Hole from 8,129' to 8,420' MOl 6,209' TVD (T.D.) ART 4 Hrs, 20K WOB, 110 Rpm's, 120 Spm, 350 Gpm's, Off Btm Press 1,700 Psi, On Btm 1,960 Psi, Off Btm Torque 15K Ft#'s, On Btm 16.5K Ft#'s, Rot WT 165K, PU 250K, On Wt 118K, 11.8 ppg Mw with 12.8 ECD, Ave BGG 150-200 WIDrig, Mud Losses Ave 24 Bph and Decreased to 12 Bph at TO, Cont Adding 8 ppb LCM to Mud WIDrig Circ 3 Btms Up to Monitor Gas & Losses, Circ @ 350 Gpm's @ 1,630 Psi. At Btms Up Max Conn Gas 1,420 Unit from an Ave BGG of 80 Units, Ave 15 Bph Mud Loss W ICirc, Circ Hole Clean, 11.8 ppg Mud Wt In & Out with ECD of 12.6 ppg, Clean Hole ECD = 12.7 ppg Circ & Raised Mw from 11.8 ppg to 12.0 ppg and Adding 8 ppb LCM to Mud W/Circ Hole at 250 Gpm at 910 Psi, ECD W/Circ at 12.6 ppg, Ave BGG 80 Units, Losses Ranging from 6-12 Bph Loss, Printed: 1/31/2003 3:08:31 PM ) ) CbriocbPhHlipsAIa.ska Q:peråtlorlsSl.im l11ary .FI~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-15 3S-15 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Date From 0; To Hours Code Sub Phase Code 1/17/2003 22:00 - 00:00 2.00 DRILL CIRC PROD 1/18/2003 00:00 - 01 :00 1.00 DRILL CIRC PROD 01 :00 - 01 :30 0.50 DRILL OBSV PROD 01 :30 - 03:00 1.50 DRILL CIRC PROD 03:00 - 06:00 3.00 DRILL CIRC PROD 06:00 - 07:00 1.00 DRILL OBSV PROD 07:00 - 09:00 2.00 DRILL WIPR PROD 09:00 - 10:00 1.00 DRILL WIPR PROD 10:00 - 14:00 4.00 DRILL CIRC PROD 14:00 - 14:30 0.50 DRILL CIRC PROD 14:30 - 00:00 9.50 DRILL TRIP PROD 1/19/2003 00:00 - 01 :30 1.50 DRILL TRIP PROD 01 :30 - 03:30 2.00 DRILL CIRC PROD 03:30 - 09:00 5.50 DRILL TRIP PROD 09:00 - 13:30 4.50 DRILL TRIP PROD 13:30 - 16:30 3.00 DRILL TRIP PROD 16:30 - 17:30 1.00 DRILL CIRC PROD Spud Date: 1/10/2003 End: Group: Start: 1/10/2003 Rig Release: 1/25/2003 Rig Number: Land Description of Operations Last 24 Hrs Lost 136 bbls of Mud, Total Since Loosing Circ 299 bbls, Also Sent 269 bbls ( LCM) to G & I Using Super Suckers Due to ball Mill Unable to Handle LCM Fin Circ Hole Raising Mw from 11.8 ppg to 12.0 ppg, Circ @250 Gpm @ 915 Psi with 70 Units BGG, 12.0 ppg In & Out ECD=12.6 Performed Exhale Test, After 30 Min Well Breathed 20 bbls Back, Initially 1 bpm then Slowed to .2 bpm after 20 Min Circ Btms Up, Max gas 2,275 Units and Dropped Out to an Ave Bgg of 80 Units, Circ @ 250 Gpm @ 900 Psi with 12.0 ppg Mud ECD=12.0 ppg Circ & Raised Mw F/12.0 to 12.3 ppg, Circ @ 250 Gpm @ 910 Psi, While Circ Losses Increased to 35 Bph Slowed Pump to 160 Gpm @ 575 Psi till 12.3 ppg mud In & out, Ave BGG 80 Units Performed 2nd Exhale Test, After 35 Min Well Breathed 16.5 bbls Back, Initially 1 bpm then Slowed to .2 bpm after 20 Min Pumped Out of hole from 8,420' to 7,616', Started Losing Returns Fn,709'-7,616', Hole Tight 30-40K Over & Torque 20-25K Ft#'s, Circ @ 2.6 Bpm @ 425 Psi, Lost 138 bbls on Trip TI H to Btm Slow Est Circ and Stage Pump Rate up to 72 Spm, 210 Gpm @ 900 Psi, Losing 20 Bph, @ Btms Up Trip Gas 640 Units, Ave Bgg 50-150 Units, Added 20 ppb LCM to System Pumped 45 bbl of 30 ppb LCM Pill, Pumped 5 bbls Out of Bit Backreamed Out Spotting Reamaining LCM Pill on Btm, Cont to Backream Out Due to Hole Not Taking Proper Fill, Circ 1 1/2 Bpm @ 300 Psi & 50 Rpm's, BHA Possibly Balled Up Causing Swabbing & Surging, Pulled 25K Over at 7,711'-7,234' with 25K Torque, Worked Thru Same, Pulled 20K at 5,481' & Worked Thru Same, Cont to Rotate & Pump Out to 4,200' Note: Lost 271 bbls Mud Last 24 Hrs and Sent 269 bbls (LCM) to G & I Using Super Sucker Due to Ball Mill Not Able to Handle LCM Last 24 Hrs (Total Mud Lost to Hole 570 bbls and 538 bbls LCM Hauled to G & I) Currently Under Phase 2 Weather Condition Cont to POOH to Shoe, Pumping & Rotating Out, Pump @ 11/2 Bpm & Rot at 50 Rpm's, No Problems Pulling into Shoe Circ 2 Complete Hole Volumes at Shoe, Staged Pump Up to 96 Spm 275 Gpm's @ 950 Psi with no Mud Loss, Circ Out Mainly LCM, Max Gas 95 Units, Ave 40 Units Bgg Monitored Well @ Shoe 20 Min & Well-Static, Cont POOH Pumping Out Due to Not Getting Proper Fill, Began Getting Proper Fill in Vertical Section, POOH to Quad Combo Tool, Monitored Well @ 2,860' & @ BHA, Well-Static Field Under Phase 3 as of 08:30 Hrs Held PJSM, Removed Nuclear Source & Down Loaded MWD, LD BHA and Cleared Rig Floor, Hole Took a Total of 31 bbls Over Calc Fill on Trip Out. BHA Balled Up PU & MU 8 1/2" Hole Opener on BHA #3 & TIH Slow to 3,501' Circ Btms Up @ Shoe, Staged Pump Up to 82 Spm, 240 Gpm's, 400 Printed: 1/31/2003 3:08:31 PM ) ) CohoCÖPhillips Ala.ska. ;()pera~iol1sSÙmmaryRéport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date, 3S-15 3S-15 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 1/10/2003 Rig Release: 1/25/2003 Rig Number: Land Spud Date: 1/10/2003 End: Group: Sub Code 1.00 DRILL CIRC PROD 2.00 RIGMNT RSRV PROD 3.00 WAlTON WOW PROD 1/19/2003 16:30 - 17:30 17:30 - 19:30 19:30 - 22:30 22:30 - 00:00 1.50 WAlTON WOW PROD 1/20/2003 00:00 - 01 :00 1.00 WAlTON WOW PROD 01 :00 - 06:00 5.00 WAlTON WOW PROD 06:00 - 07:30 1.50 WAlTON WOW PROD 07:30 - 10:00 2.50 WAlTON WOW PROD 10:00 - 12:00 2.00 DRILL TRIP PROD 12:00 - 12:30 0.50 DRILL CIRC PROD 12:30 - 14:30 2.00 DRILL TRIP PROD 14:30 - 15:30 1.00 DRILL CIRC PROD 15:30 - 16:00 0.50 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL REAM PROD 16:30 - 18:00 1.50 DRILL CIRC PROD 18:00 - 18:30 0.50 DRILL REAM PROD 18:30 - 20:30 2.00 RIGMNT RGRP PROD 20:30 - 22:00 1.50 DRILL REAM PROD 22:00 - 23:30 1.50 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL REAM PROD 1/21/2003 00:00 - 01 :30 1.50 DRILL REAM INTRM1 01 :30 - 04:00 2.50 DRILL CIRC INTRM1 04:00 - 12:00 8.00 DRILL TRIP INTRM1 12:00 - 15:00 3.00 DRILL TRIP INTRM1 Psi, Max Gas 33 Units Cut & Slip 125' of Drlg Line and Serviced Top Drive Circ Across Top of Hole & Monitored Well While Standying By Due to Phase 3 Weather Conditions, Well-Static, Inspected Breaks on Drawworks, Repositioned Standpipe Hose in Derrick, Cleaned Out Mud Pump Suctions & Cleaned Rig Circ & Cond Mud @ Shoe, Staged Pumps Up to 85 Spm, 240 Psi, 400 Psi, Rot Wt 80K, PU Wt, 98K, Dn Wt 68K, Torque Off Btm 5K Ft#'s, Highest Vis Out 158 @ 48 Deg. No Gas Mud Lost Last 24 Hrs 29 bbls, Total Lost 599 bbls Continue to be Under Phase 3 Conditions Circ Hole While Waiting on Phase 3 to Lift, 250 Gpm's 400 Psi with No Loss or Gas Monitored well, Circ Over Hole, No Loss Circ Hole While Waiting on Phase 3 to Lift, 250 Gpm's 400 Psi with No Loss or Gas Monitored well, Circ Over Hole, No Loss PHASE 3 LIFTED RIH with 8 1/2" Hole Opener on BHA #3, Staged in Hole Ran 6 Stds, Pumped 50 bbls 12.3 ppg Mud to Move Old Mud Up Hole & RIH Add 6 Stds to 4,640' Circ Btms Up at 83 Spm, 245 Gpms, 550 Psi No Losses Cont RIH to 5,210', Pumped 50 bbls Mud, RIH to 5,781' Circ Btms Up at 83 Spm, 245 Gpms, 550 Psi, No Losses, Btms up gas 290 Units RIH to 6,162' & Lost Returns, Pumped 6.5 bbls & Regained Circ, Pumped Add 50 bbls, Monitored Well-Static Washed Down from 6,162' to 6,732',50 Spm, 150 Gpm's, 480 Psi & 40 Rpm's, No Problems Washing Down Circ Btms Up, Staged Pump Up to 80 Spm, 240 Gpm's, 670 Psi, Max Gas 700 Units Washed from 6,732' to 6,923',150 Gpm's, 480 Psi & 40 Rpm's RU & Circ Hole Thru Cement Line, Changed Out Saver Sub on Top Drive Washed from 6,923' to 7,304', Pumped 50 bbls Mud, Cont Washing Down, at 7,495' Noticed Were Only Getting Partial Returns Circ Btms Up Staging Pump to 250 Gpm's, 890 Psi, Ave 20 Bph Losses W/Circ Btms Up, Max Gas 430 Units RIH from 7,495' to 7,876' No Problems, Washed from 7,876' to 8,000', 150 Gpm's, 470 Psi, 50 Rpm's, No Tight SpotsWhile RIH with Hole Opener and Washing Down Received Waiver on Testing of BOPE from John Crisp W/AOGCC Wash & ream f/8,000' to 8,420' (TD) Circ 2 BU. 250 gpm wI 840 psi. Max 2275 units of gas on bttms up. Monitor losses, 12 bph. Pump out of hole f/8,420' to 6,923'. Continue to POOH 30min/stand while pumping across shale shakers to sift out LCM. Record torque and drag data. SLM. Monitor losses-can't tell of any losses. Continue to POOH wi pumps to 5305'. 25k overpull @ 5,445'. Work through. OK. Continue POOH wI trip tank fl 5,305' to 3,501' (casing shoe). SLM. Printed: 1/31/2003 3:08:31 PM ) ) Monitor well @ 9 5/8" casing shoe. Static. BOP drill, well secure 1 min 10 sec. Continue POOH to BHA. Monitor well. OK. Lay down BHA. Clear rig floor. No correction on SLM. Pull FMC wear bushing. Rig up Frank's fillup tool and GBR casing equipment. PJSM wI company rep and tool pusher on running 7" casing. Run 7" casing. Bakerlock first 4 connections and pin on float collar. Joint 23 in hole @ midnight. Depth = 973'. Insatll centralizers on all joints. Continue running 7" 26#/ft L-80 BTC-Mod f/973' to 3561' (JT # 84). PU wt 95K SO wt 60K Displacement total of 5 bbls behing @ casing shoe. Running speed 20 fVmin- 30 fVmin 1.00 CASE CIRC INTRM1 Circulate bttm up. Starting @ 2 bpm(30spm) wI 450-480 psi. Raise rate to 2.4 bpm (34spm) wI 370-420 psi. Raise rate to 3.1 bpm (45spm) wI 360 psi declining to 200 psi by bttm's up. Raise rate to 4bpm (57spm) wI 270-310 psi after bttm's up. circ total of 2600 strokes (181 bbls). Initial MW out 12.3 wI 120 FV Final MW out 12.3 wI 50 FV MW in 12.3 wI 45 FV No losses while circulating. 4.00 CASE RUNC INTRM1 Continue running 7" 26#/ft L-80 BTC-Mod f/3561' to 5133' (JT # 121). Circ 50 bbls on jt # 100 @ 4237'. Decrease in displacement on jt # 107(4537'), circ 50 bbls on jt # 110 (4667'). Running speed 20-30 fVmin Circulate bttm's up @ 5133' (Jt # 121). Circ 136 bbls (1950 strokes) 4 bpm rate = 475-502 psi., Had good circ- gained 10.3 bbls while circ. Continue running 7" 26#/ft L-80 BTC-Mod f/5133' to 5768' (JT # 136). Good displacement Running speed 20-30 fVmin Circ 50 bbls on jt # 136 @ 5768'. Continue running 7" 26#/ft L-80 BTC-Mod f/5768' to 5982' (JT # 141). Losses fl running 5 joints were 3.5 bbls. Running speed 20- 30 fVmin Circulate bttms up @ 5982' (jt # 141) 3.5 bpm(50spm) =390 psi. Circ2300 strokes = 160 bbls., No mud loses. Continue running 7" 26#/ft L-80 BTC-Mod fl 5982' to 6455' (JT # 152). (Good displacement fl 5982' to 6195'- Lost 4 bbls fl 6195' to 6455') Running speed 20-30 fVmin Circ 50 bbls on jt # 152 @ 6455'. 2.8 bpm(40spm) = 480 psi (No mud lost while circ.) Continue running 7" 26#/ft L-80 BTC-Mod f/6455' to 6751' (JT # 159). Running speed 20-30 fVmin Circ 50 bbls on jt # 159 @ 6751'.2.1 bpm(30 spm) = 580 psi (18 bbls lost while circ.) Continue running 7" 26#/ft L-80 BTC-Mod f/6751' to 7005' (JT # 165). Running speed 20-30 fVmin While circ Bttm's up @ 7005' (jt # 165), returns went to zero. Circ @ 2.1 bpm(30spm) wi 580 psi. Attempt to regain circulation. Pump out wI Frank's tool. Lay down casing fl jt # 165 to jt # 157 (9 jts)(7005- to 6624'). No improvement in returns. Pump 15ppb LCM @ 12.1 ppg while recip pipe fl 6624' to 6580'. Pump total of 2000 strokes(139 bbls) @ 440 psi. No great improvements seen. Legal Well Name: 3S-15 Common Well Name: 3S-15 Event Name: ROT - DRILLING Contractor Name: n1268 @conocophillips.com Rig Name: Nabors 7ES Da.te From..; To Hours Code 'Sub Phase, Code 1/21/2003 15:00 - 17:00 2.00 DRILL TRIP INTRM1 17:00 - 18:30 1.50 DRILL TRIP INTRM1 18:30 .. 19:00 0.50 DRILL OTHR INTRM1 19:00 - 20:30 1.50 CASE RURD INTRM1 20:30 - 21 :00 0.50 CASE SFTY INTRM1 21 :00 - 00:00 3.00 CASE RUNC INTRM1 1/22/2003 00:00 .. 04:00 4.00 CASE RUNC INTRM1 04:00 .. 05:00 05:00 .. 09:00 09:00 .. 10:00 1.00 CASE crRC INTRM1 10:00 - 11 :00 1.00 CASE RUNC INTRM1 11 :00 - 11 :30 0.50 CASE CIRC INTRM1 11 :30 - 12:00 0.50 CASE RUNC INTRM1 12:00 - 13:30 1.50 CASE CIRC INTRM1 13:30 - 14:00 0.50 CASE RUNC INTRM1 14:00 - 14:30 0.50 CASE CIRC INTRM1 14:30 - 15:00 0.50 CASE RUNC INTRM1 15:00 - 16:00 1.00 CASE CIRC INTRM1 16:00 - 16:30 0.50 CASE RUNC INTRM1 16:30 - 18:00 1.50 CASE CIRC INTRM1 18:00 - 21 :30 3.50 CASE OTHR INTRM1 21 :30 - 23:00 1.50 CASE CIRC INTRM1 Start: 1/10/2003 Rig Release: 1/25/2003 Rig Number: Land Spud Date: 1/10/2003 End: Group: Printed: 1/31/2003 3:08:31 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') qonocoPhillips· Alaska Op.er~ti()Î1SSum marYF1~port 3S-15 3S-15 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Date" Sub From;' TO Hours · Code Code.· Phase 1/22/2003 23:00 - 00:00 1/23/2003 00:00 - 02:00 02:00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 14:00 14:00 - 18:00 Start: 1/10/2003 Rig Release: 1/25/2003 Rig Number: Land Spud Date: 1/10/2003 End: Group: 1.00 CASE OTHR INTRM1 Pump out wI Frank's tool. Lay down casing fl jt 156 to jt 153 (4 jts) 6624' to 6455'). Change out cup on Frank's fillup tool. 2.00 CASE CIRC INTRM1 Pump 15 ppb 12.1 ppg mud trying to regain circ with?" csg shoe being reciprocated fl 6412' to 6455' Üt # 152) . Finish filling casing volume plus 50 bbls outside of shoe. Total volume pumped this time 157 bbls (2254 strokes). Makes total of 297 bbls mud wI LCM pumped. Cap of casing @ 6455' = 247 bbls. No circulation, 29spm (2bpm) wI 458 psi. 1.50 CASE RUNC INTRM1 Continue running 7" 26#/ft L-80 BTC-Mod f/6455' to 6918' (JT # 163). Runnig speed 12 ftImin. No returns. 0.50 CASE CIRC INTRM1 Pump 15ppb LCM @ 12.1 ppg while recip pipe f/6918' to 6875'. Pump total of 287 strokes(20 bbls) @ 1.6 bpm (23spm) wI 425-430 psi. No circulation. PU wt 170-175k SO wt 85k 1.00 CASE RUNC INTRM1 Continue running 7" 26#/ft L-80 BTC-Mod f/6918' to 7346' (JT # 173). Runnig speed 12 ftlmin. No returns. 0.50 CASE CIRC INTRM1 Pump 15ppb LCM @ 12.1 ppg while recip pipe f/7346' to 7303' . Pump total of 287 strokes(20 bbls) @ 1.7 bpm (25spm) wI 458 psi. No circulation. PU wt 180-185k SO wt 85-90K 1.00 CASE RUNC INTRM1 Continue running 7" 26#/ft L-80 BTC-Mod f/7346' to 7774' (JT # 183). Runnig speed 12 ftlmin. No returns. 0.50 CASE CIRC INTRM1 Pump 15ppb LCM @ 12.1 ppg while recip pipe f/7346' to 7303' . Pump total of 287 strokes(20 bbls) @ 1.6 bpm (23spm) wI 480 psi. No ci rculation. PU wt 200K SO wt 95k 1.50 CASE RUNC INTRM1 Continue running 7" 26#/ft L-80 BTC-Mod f/7774' to 8404' LANDED. (JT # 197+hnr & landing joint). Runnig speed 12 ftImin. No returns. 5.50 CEMENTCIRC INTRM1 Pump 15ppb LCM @ 12.1 ppg while recip pipe f/8404' to 8384', trying to regain circ. 2bpm(29 spm) = 504 psi, 1.5 bpm(21 spm) = 420 psi. PU wt 225K SO wt 100k Pump total of 487 bbls mud after landed. 4.00 CEMENTCIRC INTRM1 Mix & pump 54 bbls LCM pill. Pill consisted of 35 bbls mud, 10 bbls water, 70sx baracarb 50, 15 sx barafibre, 10sx baroseal, 5sx liquid casing,S sx n-seal, 5sx 0 m seal, 2 sx walnut fine,S gal defoam, 5 sx steelseal. Chase wI 4825 strokes @ 2bpm (28 spm)= 510 psi. No returns. Shut Annular, open kill line. Pressure up annulus to 100 psi. After 30min = 45 psi. Bleed pressure to zero. Open well. Attempt to PU casing. Pull to 320k, did not move. Leave casing sitting on hanger. Pump 20 ppb LCM @ 12.1 ppg ,trying to regain circ. 2bpm(29 spm) = 550 psi. PJSM on cement job. Dowell batch up cement. Dowell/Schlumberger pump 10 bbls CW100 @ 8.32 ppg, test lines to 4000 psi, pump 10 bbls CW 100 @ 8.32 ppg, shut down. Drop bttm plug, reload head wI another bottom and a top plug, pump 30 bbls mudpushXI @ 12.8 ppg @ 3.1 bpm wI 745 psi. Drop another bttm plug, follow wI 59 bbls class G cement @ 15.8 ppg pumping 3 bpm wI 780-560 psi. Shut down. Wash lines to rig floor w/3 bbls seawater @ 8.5 ppg. Drop top plug, follow wI 8.5 ppg seawater @ 3 bpm 816 psi @ 50 bbls pumped, 1000 psi @ 100 bbls pumped. 18:00 - 18:30 0.50 CEMENT CI RC INTRM1 18:30 - 19:00 0.50 CEMENTCIRC INTRM1 19:00 - 21 :30 2.50 CEMENT CI RC INTRM1 21 :30 - 22:00 0.50 CEMENT SFTY INTRM1 22:00 - 00:00 2.00 CEMENT PUMP INTRM1 Printed: 1/31/2003 3:08:31 PM Date 01/24/03 01/25/03 ) ) 3S-15 Operations Summary Report Comment Dowell continue to displace cement w/8.5 ppg seawater. CIP @ 0130 hrs 1/24/03. Check floats, OK. No returns for job. Install FMC 7" packoff. Run in lockdown screws. Test packoff to 5000 psi f/10 minutes. RU to run 3.5" tubing completion. PJSM on running 3.5" completion. Run 3.5", 9.3#/ft, L-80 EUE 8rd tubing completion. Perform injectivity test on 9-5/8" x 7" annulus. Breakdown @ 17.55 ppg EMW using 12.1 ppg fluid & 740 psi @ 9-5/8" shoe. 9-5/8" shoe @ 3561' md = 2609' tvd. Run 3.5", 9.3#/ft, L-80 EUE 8rd tubing completion. RU & pressure test 7" casing to 3500 psi f/30 min test. Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 7775.74'. Pressure 3.5" tubing to 3500 psi f/15 min. UD landing joint. RID test equipment, clear floor, install TWC. N/D BOP stack, NU tree, test tree to 5K, RID test equipment, freeze protect 7" x 3.5" annulus & 3.5" tubing, install BPV, secure well, UD DP, UD mouse hole, RID injection line. Release rig @ 1900 hrs. Page 1 of 1 2121/2003 Date 02/18/03 02/23/03 03/03/03 03/15/03 03/16/03 ') ) 35-15 Event History Comment BPV REMOVED. DRIFTED TBG 2.7211 & TAGGED @ 8220' RKB,EST. 1021 BELOW TARGET PERFS. DRIFTED TBG W/22' X 2.511 HC DMY GUN TO 8220' RKB. DV SET @ 7662' RKB. MITT 3000 PSI, GOOD. MITIA 3000 PSI, GOOD. [TAG, GLV, MIT] CEMENT BOND LOG W/ SCMT-BB, TAGGED PBTD @ 8202' ELMD, LOGGED CORRELATION & MIAN SCMT UP PASS @ 1800 FPH ACROSS JEWELRY & FOUND FAIR TO GOOD CEMENT UP TO BTM OF PROPOSED PERF ZONE @ 8130' MD. RELOGGED WITH FP CORR. FACTORS AND VERIFIED POOR TO NO CEMENT ABOVE 8130' MD. PERFORATED: 8103' - 8118', 21211 HSD 60 DEGREE PHASED 6 SPF POWERJET WI 1000 PSI UNDERBALANCE TAG @ 8194' RKB & OBTAIN SAMPLEEST 76' OF RATHOLEREPLACED 1.511 DV @ 7662' RKB W/1.511 X .2511 OV. REPLACED 111 DV'S @ 7429' & 6765' RKB & W/ GLV'S PER DESIGN.PULL 111 DV @ 5513' RKB, POCKET OPEN. IN PROGRESS. PULL 111 DV @ 3527' RKB. SET GLV'S @ 3527' & 5513' RKB PER DESIGN. TEST VALVES BY BLEEDING DOWN IA TO 0 PSI W/850 PSI ON TBG, GOOD TEST. GAS LIFT INSTALL COMPLETE. [GLV] Page 1 of 1 4/212003 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-15 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD (if applicable 8,420.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) '\ qDa~' 03-Feb-03 fiECEIVE() FEB 2 6 ~OC3 AIaekn Of. & Gel{ Q'iìE.. C:':):/1(ni~n Anch~"C Sperry..Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-15 ~'-' Job No. AKMW30003, Surveyed: 17 January, 2003 Survey Report 3 February, 2003 Your Ref: 501032044400 Surface Coor<rlinates: 5993892.07 N, 476168.97 E (70023' 39.9933" N, 150011'38.0281" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 993892.07 N, 23831.03 W (Grid) Surface Coordinates relative to Structure: 48.16 N, 286.18 W (True) Kelly Bushing: 56. 65ft above Mean Sea Level Elevation relative to Project V Reference: 56. 65ft Elevation relative to Structure: 0.55ft SpE!!r''-'Y-SU,! DRILLING SERVices A Halliburton Company Survey Ref: svy10018 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-15 Your Ref: 501032044400 Job No. AKMW30003, Surveyed: 17 January, 2003 Con 0 coPhi/lips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 0.00 0.000 0.000 -56.65 0.00 0.00 N 0.00 E 5993892.07 N 476168.97 E 0.00 Tolerable Gyro 88.00 0.500 90.000 31.35 88.00 0.00 N 0.38 E 5993892.07 N 476169.35 E 0.568 -0.21 179.00 0.600 14.000 122.35 179.00 0.46 N 0.90 E 5993892.53 N 476169.87 E 0.749 -0.12 MWD Magnetic 291.14 3.420 320.490 234.41 291.06 3.61 N 1.09W 5993895.69 N 476167.89 E 2.765 3.61 382.99 4.4 70 324.110 326.04 382.69 8.63 N 4.93W 5993900.71 N 476164.07 E 1.174 9.91 471.80 5.700 328.830 414.50 471.15 15.20 N 9.24W 5993907.30 N 476159.78 E 1 .462 17.78 561.42 7.960 333.730 503.48 560.13 24.58 N 14.29 W 5993916.69 N 476154.75 E 2.602 28.37 -- 652.20 9.010 333.060 593.26 649.91 36.55 N 20.30 W 5993928.69 N 476148.79 E 1.162 41.66 742.69 10.340 338.430 682.47 739.12 50.42 N 26.49 W 5993942.58 N 476142.64 E 1.775 56.63 832.59 13.210 335.260 770.47 827.12 67.26 N 33.76 W 5993959.44 N 476135.43 E 3.271 74.66 928.76 16.420 331.900 863.43 920.08 89.23 N 44.76 W 5993981.45 N 476124.49 E 3.454 99.05 1023.05 19.510 331.890 953.11 1009.76 114.88 N 58.46 W 5994007.14 N 476110.87 E 3.277 127.98 1119.00 23.640 332.330 1042.32 1098.97 146.07 N 74.95 W 5994038.38 N 476094.48 E 4.308 163.06 1213.58 25.680 328.830 1128.27 1184.92 180.40 N 94.37 W 5994072.77 N 476075.18 E 2.652 202.39 1308.67 27.900 326.350 1213.16 1269.81 216.56 N 117.36 W 5994109.00 N 476052.30 E 2.613 245.23 1402.77 32.240 328.110 1294.57 1351.22 256.21 N 142.84 W 5994148.74 N 476026.95 E 4.706 292.35 1497.28 37.980 329.11 0 1371.86 1428.51 302.61 N 171.11 W 5994195.23 N 475998.83 E 6.104 346.63 1592.57 42.170 329.360 1444.76 1501.41 355.32 N 202.4 7 W 5994248.03 N 475967.63 E 4.400 407.88 1687.21 45.940 329.060 1512.76 1569.41 411.84 N 236.16 W 5994304.66 N 475934.12 E 3.990 473.58 1782.35 49.590 326.840 1576.70 1633.35 471.50 N 273.56 W 5994364.44 N 475896.91 E 4.207 543.97 1877.54 53.180 329.090 1636.10 1692.75 534.56 N 312.97 W 5994427.62 N 475857.70 E 4.199 618.29 1971.73 55.120 329.700 1691.27 1747.92 600.27 N 351.84 W 5994493.45 N 475819.05 E 2.125 694.51 2065.58 56.750 325.810 1743.85 1800.50 665.98 N 393.32 W 5994559.31 N 475777.77 E 3.847 772.20 2162.74 58.160 323.590 1796.12 1852.77 732.81 N 440.66 W 5994626.28 N 475730.65 E 2.411 854.06 2258.07 57.600 326.090 1846.81 1903.46 798.81 N 487.15 W 5994692.43 N 475684.37 E 2.297 934.77 -- 2351.83 57.960 325.670 1896.80 1953.45 864.48 N 531.64 W 5994758.24 N 475640.09 E 0.539 1014.09 2448.78 57.650 324.280 1948.46 2005.11 931.66 N 578.73 W 5994825.57 N 475593.22 E 1.255 1096.11 2542.65 58.410 326.070 1998.16 2054.81 997.03 N 624.19 W 5994891.08 N 475547.96 E 1.809 1175.73 2638.01 57.930 324.100 2048.46 2105.11 1063.46 N 670.56 W 5994957.66 N 475501.80 E 1.826 1256.72 2733.29 58.160 326.720 2098.89 2155.54 1130.00 N 716.45 W 5995024.35 N 475456.13 E 2.345 1337.55 2828.76 57.880 328.670 2149.46 2206.11 1198.44 N 759.72 W 5995092.93 N 475413.07 E 1.757 1418.49 2924.57 57.810 325.610 2200.46 2257.11 1266.57 N 803.73 W 5995161.19 N 475369.29 E 2.705 1499.58 3019.40 57.400 324.710 2251 .26 2307.91 1332.29 N 849.47 W 5995227.06 N 475323.75 E 0.911 1579.64 3115.63 55.740 323.280 2304.28 2360.93 1397.26 N 896.67 W 5995292.18 N 475276.76 E 2.125 1659.89 3209.64 56.410 322.700 2356.75 2413.40 1459.54 N 943.62 W 5995354.61 N 475230.00 E 0.877 1737.77 3 February, 2003 - 10:07 Page 2 0'5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-15 Your Ref: 501032044400 Job No. AKMW30003, Surveyed: 17 January, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3304.37 56.400 323.620 2409.16 2465.81 1522.69 N 990.93 W 5995417.91 N 475182.90 E 0.809 1816.57 3399.29 55.970 325.470 2461.99 2518.64 1586.93 N 1036.68 W 5995482.29 N 475137.36 E 1.681 1895.40 3505.30 55.820 322.680 2521.44 2578.09 1658.00 N 1088.17 W 5995553.53 N 475086.09 E 2.184 1983.10 3652.31 55.590 323.300 2604.27 2660.92 1754.98 N 1161.28 W 5995650.74 N 475013.29 E 0.382 2104.37 3747.69 55.350 322.800 2658.34 2714.99 1817.77 N 1208.51 W 5995713.69 N 474966.26 E 0.500 2182.83 3842.71 54.700 323.670 2712.81 2769.46 1880.14 N 1255.11 W 5995776.21 N 474919.86 E 1.015 2260.58 3938.40 54.010 322.300 2768.57 2825.22 1942.24 N 1301.92 W 5995838.45 N 474873.24 E 1.369 2338.22 -,-- 4034.24 53.080 324.130 2825.52 2882.17 2003.96 N 1348.09 W 5995900.32 N 474827.28 E 1.817 2415.20 4129.39 52.880 327.220 2882.82 2939.47 2066.69 N 1390.92 W 5995963.18 N 474784.65 E 2.601 2491.15 4224.56 52.340 327.670 2940.61 2997.26 2130.42 N 1431.61 W 5996027.04 N 474744.16 E 0.681 2566.75 4319.18 52.030 326.650 2998.62 3055.27 2193.22 N 1472.14 W 5996089.98 N 474703.83 E 0.912 2641 .48 4413.81 51.760 326.360 3057.02 3113.67 2255.32 N 1513.23 W 5996152.20 N 474662.93 E 0.374 2715.94 4508.13 51.200 325.650 3115.76 3172.41 2316.50 N 1554.49 W 5996213.52 N 474621.87 E 0.836 2789.74 4602.79 50.850 326.690 3175.30 3231.95 2377.63 N 1595.46 W 5996274.78 N 474581.09 E 0.931 2863.33 4697.63 50.680 326.590 3235.29 3291.94 2438.99 N 1635.86 W 5996336.26 N 474540.90 E 0.197 2936.78 4792.70 50.580 326.400 3295.59 3352.24 2500.27 N 1676.43 W 5996397.67 N 474500.52 E 0.187 3010.28 4887.11 50.320 326.520 3355.71 3412.36 2560.95 N 1716.65 W 5996458.48 N 474460.49 E 0.292 3083.07 4982.15 49.740 325.610 3416.76 3473.41 2621.38 N 1757.31 W 5996519.04 N 474420.03 E 0.954 3155.91 5077.26 49.380 325.890 3478.46 3535.11 2681.21 N 1798.05 W 5996579.00 N 474379.48 E 0.440 3228.29 5172.47 49.020 326.500 3540.67 3597.32 2741 .1 0 N 1838.15 W 5996639.01 N 474339.57 E 0.615 3300.36 5268.18 48.640 326.050 3603.67 3660.32 2801.02 N 1878.15 W 5996699.06 N 474299.76 E 0.532 3372.41 5362.84 48.380 326.230 3666.39 3723.04 2859.90 N 1917.65 W 5996758.07 N 474260.44 E 0.309 3443.32 5457.63 51 ,190 326.990 3727.58 3784.123 2920.34 N 1957.48 W 5996818.63 N 474220.81 E 3.027 3515.69 5551.96 50.680 326.540 3787.03 3843.68 2981.60 N 1997.62 W 5996880.02 N 474180.87 E 0.655 3588.93 5648.25 50.300 326.720 3848.29 3904.94 3043.64 N 2038.48 W 5996942.19 N 474140.20 E 0.420 3663.21 '-' 5743.65 49.590 327.390 3909.68 3966.33 3104.92 N 2078.19 W 5997003.60 N 474100.69 E 0.918 3736.23 5839.20 49.000 327.350 3972.00 4028.65 3165.92 N 2117.25W 5997064.72 N 474061.82 E 0.618 3808.64 5932.24 48.300 326.620 4033.46 4090.11 3224.48 N 2155.30 W 5997123.41 N 474023.96 E 0.955 3878.48 6029.78 48.260 327.030 4098.38 4155.03 3285.42 N 2195.14 W 5997184.47 N 473984.31 E 0.316 3951.28 6123.94 48.140 327.100 4161.14 4217.79 3344.33 N 2233.30 W 5997243.51 N 473946.34 E 0.139 4021.46 6219.75 48.070 327.290 4225.11 4281.76 3404.28 N 2271.94 W 5997303.57 N 473907.89 E 0.165 4092.77 6315.31 47.900 326.870 4289.08 4345.73 3463.88 N 2310.53 W 5997363.29 N 473869.50 E 0.372 4163.76 6408.08 45.690 326.760 4352.58 4409.23 3520.47 N 2347.54 W 5997420.00 N 473832.67 E 2.384 4231.37 6504.65 43.390 327.280 4421.41 4478.06 3577.28 N 2384.41 W 5997476.93 N 473795.98 E 2.411 4299.09 6600.19 41.510 324.040 4491.91 4548.56 3630.52 N 2420.75 W 5997530.29 N 473759.81 E 3.018 4363.55 3 February, 2003 - 10:07 Page 3 of5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-15 Your Ref: 501032044400 Job No. AKMW30003, Surveyed: 17 January, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6694.35 39.610 323.590 4563.44 4620.09 3679.94 N 2456,89 W 5997579.83 N 473723.82 E 2.042 4424.73 6790.41 37.910 324.680 4638.35 4695.00 3728.67 N 2492.13 W 5997628.67 N 473688.74 E 1.907 4484.82 6884.62 35.800 324.750 4713.73 4770.38 3774.79 N 2524.77 W 5997674.89 N 473656.25 E 2.240 4541.31 6980.99 32.820 324.200 4793.32 4849.97 3819.00 N 2556.32 W 5997719.20 N 473624.84 E 3.109 4595.60 7076.22 29.410 324.700 4874.84 4931 .49 3859.03 N 2584.94 W 5997759.32 N 473596.35 E 3.591 4644.78 7171.67 26.660 324.350 4959.08 5015.73 3895.56 N 2610.97 W 5997795.94 N 473570.44 E 2.886 4689.62 7266.62 25.650 324.290 5044.30 5100.95 3929.56 N 2635.38 W 5997830.01 N 473546.13 E 1.064 4731.45 '~ 7361.49 24.360 323.540 5130.28 5186.93 3961.97 N 2658.99 W 5997862.50 N 473522.62 E 1.400 4771.52 7457.09 23.690 325.040 5217.60 5274.25 3993.57 N 2681.71 W 5997894.17 N 473500.00 E 0.948 4810.42 7552.10 21.130 323.840 5305.43 5362.08 4023.04 N 2702.76 W 5997923.71 N 473479.05 E 2.737 4846.62 7648.48 18.030 321.620 5396.22 5452.87 4048.77 N 2722.27 W 5997949.49 N 473459.62 E 3.307 4878.86 7740.78 15.150 320.520 5484.67 5541.32 4069.28 N 2738.81 W 5997970.06 N 473443.14 E 3.139 4905.10 7838.32 11.380 320.410 5579.59 5636.24 4086.54 N 2753.05 W 5997987.36 N 473428.96 E 3.865 4927.37 7933.82 10.530 318.870 5673.35 5730.00 4100.37 N 2764.80 W 5998001.23 N 473417.26 E 0.941 4945.40 8028.86 10.200 318.250 5766.84 5823.49 4113.19 N 2776.11 W 5998014.09 N 473405.98 E 0.367 4962.35 8124.10 9.770 319.110 5860.64 5917.29 4125.59 N 2787.02 W 5998026.52 N 473395.12 E 0.478 4978.72 8219.79 9.770 319.740 5954.94 6011.59 4137.92 N 2797.58 W 5998038.89 N 473384.59 E 0.112 4994.85 8315.09 9.240 318.310 6048.93 6105.58 4149.81 N 2807.90 W 5998050.81 N 473374.32 E 0.609 5010.46 8356.47 8.900 317.810 6089.79 6146.44 4154.66 N 2812.26 W 5998055.67 N 473369.97 E 0.843 5016.92 8420.00 8.900 317.810 6152.56 6209.21 4161.94N 2818.86 W 5998062.98 N 473363.40 E 0.000 5026.64 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.65' MSL. Northings and Eastings are relative to 2524' FNL, 1091' FEL. 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 2524' FNL, 1091' FEL and calculated along an Azimuth of 326.160° (True). Magnetic Declination at Surface is 25.2200(11-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8420.00ft., The Bottom Hole Displacement is 5026.70f1., in the Direction of 325.890° (True). 3 February, 2003 - 10:07 Page 4 of5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 35-15 Your Ref: 501032044400 Job No. AKMW30003, Surveyed: 17 January, 2003 Western North Slope ConocoPhilfips Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 8420.00 6209.21 4161.94N 2818.86 W Projected Survey . / ~- Survey tool program for 35-15 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 179.00 0.00 179.00 179.00 8420.00 179.00 Tolerable Gyro 6209.21 MWD Magnetic -..,....' 3 February, 2003 - 10:07 Page 50f5 DrillQuest 3.03.02.004 03/06/03 Schlumbergep NO. 2694 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD ~-~--,,'" 3S-15 ~o.;¡.~Sl; 3S-16aD3~ 007 23085 23084 SCMT SCMT 02123/03 02123/03 1 1 ,-,' SIG~~ úJ)OO~ -I\I"-D RECt.:t--~ t:.- - DATE: ~\v1Ar' i I ¡ j003 ;u IS \ V , .í-~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Þ.ja5~{3 G'i-; ,~ C;B~ 0::-ns. li)mrffi~n Afi2r(~a @¡rfli\~~ æJ J W _ .;::J .~ ') J !Æ~!Æ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR ~, A.I1A.~KA OIL AND GAS CONSERVATION COlWllSSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 3S-15 ConocoPhillips Alaska, Inc. Permit No: 202-254 Surface Location: 2524' FNL, 1091' FEL;Sec. 18, TI2N, R8E, UM Bottomhole Location: 1708' FSL, 876' FWL, Sec. 7, TI2N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. This permit to drill 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, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ~!'(Jay. of January, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. 9. Approximate spud date / January 8, 2003 14. Number of acres in property 2448 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3003 psig ../' At total depth (TVD) 3651 psig Setting Depth ) STATE OF ALASKA } ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test Service D Development Gas D Single Zone 5. Datum elevation (DF or KB) RKB = 28' 1a. Type of work: Drill ~ Redrill U Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 252~FNL, 1091'FEL,Sec. 18,T12N,R8E, UM At top of productive interval 1675' FSL, 898' FWL, Sec. 7, T12N, R8E, UM At total depth 1708' FSL, 876' FWL, Sec. 7, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 876' @ TO 3S-18 @ 61' / 6. Property Designation ADL 380106 ALK 4623 7. Unit or property Name Kuparuk River Unit 8. Well number 3S-15 / feet 16. To be completed for deviated wells Kickoff depth: 200 MD 18. Casing program size Maximum hole angle 53° VJGA-· / Z./~OIt!J2_ U D Development Oil ~ Multiple Zone D 10. Field and Pool Kuparuk River Field ,/ Kuparuk River Oil Pool ~/ 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 8347' MD 16111 ' TVD Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM Top Bottom Quantity of Cement Length MD TVD MD TVD (include stage data) 80' 28' 28' 108' 108' 9 cy High Early 3448' 28' 28' 3476' 2608' 550 sx AS Lite & 340 sx LiteCrete 8319' 28' 28' 8347' 6111 ' 250 sx Class G 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0 Time vs depth plot Uefraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 ....~ \\ \7.J"L"'>(ð?. Signed "--~ ~ Title: Kuparuk Drilling Team Leader Date ~. Thomas ...., PrAnarArl hv Shamn AII.C::/ln-nrakA Commission Use Only Permit Number I API number I Approval date ,. J J ,.., Isee cover letter .zo 2. - 2- _LJ ¿¡ 50- /0..3 -' .2. 0 Y -7" 7" ( ¡' (; "7 for other requirements Conditions of approval Samples required DYes l81 No Mud log required I U Yes ~ No Hydrogen sulfide measures DYes J8j No Directional survey required ~ Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D Other:T-eht- 'fÞ1rE 1-0 5000 p{,~'. 4ppwctct./l ~¡u.iY1-lJ ß;~ tt-//i"4~ utc), fy()C¡/~~ by order of 1 ORIGINAL SIGNED BY Commissioner the commission Date I l J/) ~ M L. Bill ./ /0 '.J o ~ ¡ G ¡,~JA_ Hole Casing Weight 42" 16" x 30" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: Plugs (measured) measured true vertical feet feet Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Production Length Size Cemented Perforation depth: measured true vertical Approved by Form 10-401 Rev. 12/1/85- Measured depth True Vertical depth R'E€!fVHD DEC 2 J 2002 AlasRaOiJ·& Gas Qons. Commlsslo.n Anchorage . Submit in triplicate ~.,',) ConocoPhillips ) , Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com December 19, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 3S-15 Dear Commissioner Taylor: / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 3S-15, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~,~. Randy Thomas GKA Drilling Team Leader OR r. ..:~ ~ '~"J J '¡l;Î i¡\. I~~)' ) AppP'"1jon for Permit to Drill, We1l3S-15 ) Revision No.O ) Saved: 17-Dec-02 Permit It - Kuparuk Well 35-15 Application for Permit to Drill Document M()ximizE Well ValUE; Table of Contents 1. Well Name.... ..... ..................... ........... ..... ........ ..... ......................... .... ..... ........ ....... ..... 2 Requirements of 20 AAC 25.005 (f)........ ................................................ ................................................ 2 2. Location Sum mary ........ ..... .............. ........ ..... .... .......... ....... ................. ... .............. .... 2 Requirements of 20 AAC 25.005(c)(2) ....... ................................................ .............. .............................. 2 Requirements of 20 AAC 25. 050(b)............ ............................................... ............................................. 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information......... .......... ..... .... ... ......... ................... ....... ........... ...... 3 Requirements of 20 AAC 25.005 (c)( 4) ...... ............................................... ............. ................................ 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .. ........................................................................................... ..... 3 6. Casi ng and Cementi ng Program............ ..... .......... ....... ..... ................... .............. ..... 4 Requirements of 20 AAC 25. 005( c)(6) ...................................................... ............................................. 4 7. Diverter System Information ..... ...... .... ...... .... .... ... ......... ....... ....... ..... ......... ..... ......... 4 Requirements of 20 AAC 25.005(c)(7) .. ................ ........ ...... ............................... ........................ ............ 4 8. Dri II i ng FI u id Program ............. ......... ....... .... ........ .............. ..... ... ............. ... ........ ...... 4 Requirements of 20 AAC 25. 005( c)(B) ............. ................ ........................ .............................................. 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ................... ............ ................................ ................................... 5 10. Seism ic Analysis................. ......... ........ ........ .... ........... ...... ... ..... ......... ..... ............ ..... 5 Requirements of 20 AAC 25.005 (c)(10) ......... ....................................... ................ ......................... .......5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ......... ....................................................... ......................... ....... 6 12. Evidence of Bondi ng .... .......... ..... ... ......... ...... ............ .... ....... ........ .... ..... ... ... ....... ..... 6 Requirements of 20 AAC 25.005 (c)(12) .... ...................... ......... ........ ......... ......................... ................... 6 13. Proposed Drilli ng Program . ............ .............................. ........ ... .... ..... ..... .... ........ ..... 6 OR·ro:" ,.".".,'" ..",.",. ,"~," ' ,Î i G; I J"J i1 :.. 38-15 PERM/T /T.DOC Page 1 of 7 Printed: 17-Dec-02 ) Appli"'q,tion for Permit to Drill, Well 3S-15 } Revision No.O , Saved: 17-Dec-02 Requirements of 20 AAC 25.005 (c)(13) ........................... ............. ................... ................... .................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ............... ............... ...................... ........... ......... ............ ............ 6 15 . Attach m e nts ............................................................................................................. 7 Attachment 1 Directional Plan...... ...................................... ......................... .......................................... 7 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic.............................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name des~qnated by the operator and a unique API number assigned by the commission LInder 20 AAC 25.040(b). FiJI' a well with multiple wf:?11 brlmche:,~ each branch must similarly be Identified by a unique name and API number by adding a suffix to the name de."ìflnated for the well by ttle operator and to the number a,ssigned to the well by the commission. / The well for which this application is submitted will be designated as 35-15. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applicatio/7 fÒr a Permit to Dlill must be accompanied by eaäl of" the following items~ except for a/7 item already 0/7 tile with the commission and identified in the application: (2) c:J plat IdentifyJÌ1{J the property and the prope¡ty's owners and showing (A)the (:vordinates olthe proposed location of the well at the su¡fåce~ at the top of each oL?jective formðtion and at total depth referenced to governmental section lines... (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for tMt; state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Sulface NGS Coordinates Northings: 5,993,892 12524' FNL, 1091' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,169 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,998,100 1675' FSL, 898' FWL, Sec 7, T12N, R8E, UM Eastings: 473,367 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8122' 5889' 5833' Location at Total Depth 11708' FSL, 876' FWL, NGS Coordinates Northings: 5,998,133 East/ngs: 473,345 Sec 7, T12N, R8E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8347' 6111' 6055' and (D) other information requ/Ì-ed by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PermIt to Dnll (Form 10-401) must (1) include a pla0 drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent well bores within 200 feet of any portion of the proposed welf,' Please see Attachment 1: Directional Plan C=' GiNt- 3$-15 PERM/T /T.DOC Page 2 of 7 Printed: 17-Dec-02 ) APPJi""",tion for Permit to Drill, We1l3S-15 I Revision No.O . Saved: 17-Dec-02 and (2) for all we/Is within 200 feet of the proposed we/lbore (A) list the names of the operators of those wells~ to the extent that those names are known or di!:>y:oven:1ble in public record!;'"" and show that each named operator has been furnished a copy of the application by certified mall,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Pel7l71t to Drill must be accompanied by each of the followlÍ7g Item5~ except for an Item already on file with the commission and identified in the application: (3) a diagram and descliptiol7 of'the blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.036, or 20 AAC 25.037; as applicable,: / Please reference BOP schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the tollowing ¡{em5~ except tor an item already on file with the Gvmmis..c,io!1 and identttìed in the application: (4) int'onrJation on drilling hazardS¡ including (A) the maximum downhole pressure that may be encounterect cntetia used to detenT/ine i~ and maximum potentit.11 surface pressure based 017 a methane gradient; A pressure build-up test performed on Palm 1A (35-26) .~~~" A' ' 1 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or~ ppg EMW (equivalent mud weight). The maximum potential surface pressure (MP5P) while drilling 35-15 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5889' tvd: MPSP =(5889 ft)*)9.62 - 0.11 psi/ft) = 3003 psi (8) data on potential gas zones,: The well bore is not expected to penetrate any gas zones. and (C) data concerning potent/~;¡1 CaIiSé?S of hole problems slich as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential stickif7g/' Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to 01"111 must be accompanied by each of the fallowing item~ except for an item already 0/7 file with the commission and Identified in the application: (5) a descriptio/7 of the procedure for conducting formation integrity test~ as required under 20 AAC 25. 030(f}; A procedure is on file with the commission for performing LOT's. For 35-15 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) C :. G 'Nt - 3$-15 PERM/T IT. DOC Page 3 of 7 Printed: 17-Dec-02 ) Appj"1'on for Permit to Drill, We1l3S-15 Revision No.O , Saved: 17-Dec-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by eaä7 of ttle following item5~ except for an Item already on file with the (,"0171mis:,70n and identified in the applkãtion: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030/ and a description of any slotted liner; pre- perforated liner; or screen to be ¡ì7stalle~' Casinq and Cementinq Program Hole ./ /' Top Btm CsglTbg Size Weight Length MDITVD MD/TVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 3448' 28'/28' 3476'/2608' Lead: 550 sx 10.7 ppg AS Lite Tail: 340 sx 12.0 ppg 'LiteCR~l (Yield= .~b cuft/sk) /' Planne¡;,fOC=Surface 7 8-1/2 26 L-80 BTC-Mod 8319' 28'/28' 8347'/6111' 250 sx 15.8 ppg 'G' w/ add. Planned TOC= 7321' 3-1/2 9.3 L-80 EUE 8rd 7994' 28' / 28' 8022'/5791' SAB- 3 packer set at Mod 8022' MD. An open-hole leak-off test will be performed on the 8 '12/1 open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7/1 casing will be top-set above the Kuparuk C sand. In this case, 6 1/8/1 hole would be drilled to total depth and a 3 '12/1 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items., except for an item already on file with the commission and identified in the application: (1) a diagram and description of the diverter system as required by 20 AAC 25. 035, unless this requirement is waived by the commis:c,ion under 20,AAC 25.035{I1){2)/ Please reference diverter schematic on file for Nabors 7ES. / 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pe/771/t to Drill mw:t be accompanied by each of the followli7g ¡tems, except for an Item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25. 033/' Drilling will be done using mud systems having the following properties: (1QI~'^,At 3S-15 PERMIT /T.DOC Page 4 of 7 Printed: 17-Dec-02 ') APpIÕ-1!, ion for Permit to Drill, We1l3S-15 J Revision No.O Saved: 17-Dec-02 Suface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value J' Density (ppg) 8.6 9.0* 9.0* 9.4* /" Funnel Viscosity 120-130 120-130 120-130 120-130 (seconds) Yield Point 35-45 27 -40 25-35 20-30 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (/b1100 sf) 10 second Gel 10-30 1 0-25 1 0-25 10-25 Strength (/b1100 sf) 10 minute Gel 25-55 25-55 20-40 15-35 Strength (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 12-15 7-8 7-8 7-8 Solids (%) 6-9 6-12 6-12 6-12 * 9.8 if hydrates are encountered Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk /' Density (ppg) 9.5 10.2 10.6 10.8 12.3 Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (/b1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (/b1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (/b1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 1 5-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pelmlt to D/ill must be accompanied by each of the follow¡í7g Items, except for an Item already on file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out tl7e depths of predicted abnormally geo-pressured strata as required by 20 MC 25. 033(f}/ N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a)/" N/ A - Application is not for an exploratory or stratigraphic test well. rD'~/^,At 3S-15 PERMIT IT. DOC Page 5 of 7 Printed: 17-Dec-02 ) App:-"'~on for Permit to Drill, We1l3S-15 J Revision No.O Saved: 17-Dec-02 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Perrmt to Drill must be accompanied by each of the following Item5~ except for an Hem already on file with the c;ommission and identifìed in the application: (1.l) f'or a well drilled finm an offshore platform; mobile bottom-f'ounded struäure; jt7ck-up I'l!}; or floating drilling vessel, an analysis of seabed condItions as required by 20 AAC 2s'061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a perrmt to Drill mllst be accompanied by each of the following iterm""; except for an item already on file wIth the COfT1rrl/'5:c,ion and identttied in the application: (12) evidence showing that the requirements of 20 AAC 25,025 (Bonding}!7ave been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be aCL""Ompanied by each of the f'ollowing items; except f'or an item already on file wIth the commi:'"'5ion and Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. / 2. Install diverter system. / 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. No LWD logs are planned. /'/ 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surfac;.z,If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. ./ 5. Drill out cement and 20' of new hole. Perform LOT. / 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. POOH and P/U neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L -80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030( d)(3)(C). ' 7. Run 3-1/2" 9.3#, L-80 8rd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and /' PBR. Set packer, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. / 9. Freeze protect. Secure well. Rig down and move out. / 10. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L -SO BTCM ~ casing will be run and cemented above the Kuparuk C sand. 6 l/S" hole will be drilled to total depth * according to the directional plan and a 3 '/2" 9.3# L-SO SLHT liner will be ran and cemented across the productive interval. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items; except for an item already on file wIth the commis..c;lon and identltìed in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25,080 for an annular disposal operation in the well.; C J Lf' I'~ ::,f ,A , ¡ i '1 H P'¡"i V) g ¥ tJ :ts8 3$-15 PERMIT IT. DOC Page 6 of 7 Printed: 17-Dec-02 ) APP,:-q}tion for Permit to Drill, We1l3S-15 Revision No.O Saved: 17-Dec-02 Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 35-15 for annular pumping of / fluids occurring as a result of future drilling operations on 35 pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. (R¡'f1L~'AL 'l4iiVf\ 38-15 PERMIT IT. DOC Page 7 of 7 Printed: 17-Dec-02 Western North ConoGfl~lI, 35-15 Plan :"~3S~15 (wp03) Sperry-Sun Drilling Services .~" Revised: 16 September, 2002 roposal Report 18 December, 2002 Your Ref: Intersect Target wI 100 Inc. Surface Coordinates: 5993892.00 N, 476169.03 E (70023' 39.9926" N, 209048' 21.9736" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level --' spel'''Y-5UI! DAí-CLING~C""'~E$_ffYJ'êlæs A Halliburton Company Proposal Ref: pro9979 c=-. 'G i NA... DrillQuest 3.03.02.005 Page2of7 O· ~'a'A . ·t , .1 1\"'·- 18 December, 2002 - 11:33 Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target wI 10° Inc. Revised: 16 September, 2002 ConocoPhi//ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastinas¡¡i¡ RátØ Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -56.1 0 0.00 0.00 N 0.00 E 5993892.00 N 0.00 SHL (2524' FNL & 1091' FEL, SEC. 1 T12N - R8E) 100.00 0.000 0.000 43.90 100.00 0.00 N 0.00 E 5993892.00 N 0.000 0.00 200.00 0.000 0.000 143.90 200.00 O.OON 0.00 E 5993892.00 N 0.000 0.00 Begin Oir @ 2.0°/1 o Oft (in 12-1/4" Œ97W Hole): 200.00ft MO, 200.00ft TVD 300.00 2.000 326.158 243.88 299.98 1.45 N 5993893.45 N 476168.06 E 2.000 1.75 400.00 4.000 326.158 343.74 399.84 5.80 N 3.89W 5993897.81 N 476165.16 E 2.000 6.98 ~ 500.00 6.000 326.158 443.35 499.45 1;ª~03 N 8.74 Wl 5993905.06 N 476160.33 E 2.000 15.69 600.00 8.000 326.158 542.60 598.70 2'''16 N 15.53 W 5993915.21 N 476153.58 E 2.000 27.88 700.00 10.000 326.158 641 .37 697.47 ic!¡¡¡Pi'ÎJ§ N 24.24 W 5993928.23 N 476144.91 E 2.000 43.52 Increase in Dir Rate @ 4.0°/1000 : 700.00ft MD, 697.47ft TVD 800.00 14.000 326.158 739.16 795.26 ~;l,4;'j¡;N} 35.81 W 5993945.53 N 476133.39 E 4.000 64.31 900.00 18.000 326.158 835.27 891.37 76.30 N 51.16 W 5993968.47 N 476118.11 E 4.000 91.87 1000.00 22.000 326.158 929.22 985.32 104.70 N 70.20 W 5993996.93 N 476099.16 E 4.000 126.06 1100.00 26.000 326.158 1020.55 1076.65 138.48 N 92.85 W 5994030.78 N 476076.62 E 4.000 166.73 1200.00 30.000 326.158 1108.83 1164.93 177.47 N 118.99 W 5994069.84 N 476050.61 E 4.000 213.67 1300.00 34.000 326.158 1193.62 1249.72 221.47 N 148.50 W 5994113.94 N 476021.24 E 4.000 266.65 1400.00 38.000 329.158/ l2?4.5Ö 1330.60 270.28 N 181.22W 5994162.86 N 475988.67 E 4.000 325.41 1500.00 42.000 . 3~6;t58 . 1351.09 1407.19 323.66 N 217.01 W 5994216.35 N 475953.05 E 4.000 389.68 1600.00 46.000 326.158 1423.01 1479.11 381.34 N 255.69 W 5994274.16 N 475914.56 E 4.000 459.13 1700.00 . . 50 .000 ..., 328.158' 1489.91 1546.01 443.06 N 297.07 W 5994336.00 N 475873.38 E 4.000 533.43 1700.14 50.006 326.15à 1490.00 1546.10 443.15 N 297.13 W 5994336.09 N 475873.32 E 4.000 533.54 B. Permafrost 1783.39 53.336 326.158 1541.63 1597.73 497.38 N 333.49 W 5994390.44 N 475837.13 E 4.000 598.84 End Dir, Start Sail @ 53.34° : 1783.39 MD, 1597.72ft TVD .~ 1800.00 53.336 326.158 1551.54 1607.64 508.45 N 340.91 W 5994401.53 N 475829.74 E 0.000 612.16 1900.00 53.336 326.158 1611.25 1667.35 575.07 N 385.58 W 5994468.30 N 475785.28 E 0.000 692.37 2000.00 53.336 326.158 1670.97 1727.07 641.70 N 430.25 W 5994535.06 N 475740.82 E 0.000 772.59 2100.00 53.336 326.158 1730.68 1786.78 708.32 N 474.93 W 5994601.83 N 475696.37 E 0.000 852.80 2200.00 53.336 326.158 1790.39 1846.49 774.95 N 519.60 W 5994668.60 N 475651.91 E 0.000 933.02 2300.00 53.336 326.158 1850.10 1906.20 841.57 N 564.27 W 5994735.37 N 475607.45 E 0.000 1013.23 2400.00 53.336 326.158 1909.82 1965.92 908.20 N 608.94 W 5994802.13 N 475562.99 E 0.000 1093.45 2475.67 53.336 326.158 1955.00 2011.10 958.61 N 642.74 W 5994852.65 N 475529.35 E 0.000 1154.14 T. West Sak 2500.00 53.336 326.158 1969.53 2025.63 974.82 N 653.61 W 5994868.90 N 475518.53 E 0.000 1173.66 2600.00 53.336 326.158 2029.24 2085.34 1 041 .45 N 698.28 W 5994935.67 N 475474.07 E 0.000 1253.88 DrillQuest 3.03.02.005 J J/?fftt7jt , ., UliV¡:',. 18 December, 2002 - 11:33 Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target wI 10° Inc. Revised: 16 September, 2002 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastinašij¡;, Rám .. Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 2700.00 53.336 326.158 2088.95 2145.05 1108.07N 742.95 W 5995002.43 N 1334.09 2800.00 53.336 326.158 2148.67 2204.77 1174.69 N 787.63 W 59950§ª.20 N 0.000 1414.31 2900.00 53.336 326.158 2208.38 2264.48 1241.32 N 832.30 W 59ªªª~iI7 N 0.000 1494.52 3000.00 53.336 326.158 2268.09 2324.19 1307.94 N 876.97 W,,~59&~02:~I;N 0.000 1574.74 3100.00 53.336 326.158 2327.80 2383.90 1374.57 N 921¡,¡4 VYi;!f'ì¥j;¡j!~9~'9 .St§;N 0.000 1654.95 ·~::X:~ ._:':::.... .._......;.... :n:::_:.,,". -::,;-"-- - -- ~:':::::;'. ":.:..--"': 3200.00 53.336 326.158 2387.52 2443.62 1441.19N 966.31 W '1Iil[~5336.27 N 475207.32 E 0.000 1735.17 -- 3220.91 53.336 326.158 2400.00 2456.10 1455.12 N 975.65 W;\~± 5995350.23 N 475198.02 E 0.000 1751.93 B. West Sak 3300.00 53.336 326.158 2447.23 2503.33 15Q!i182 N ~,:.;.i1;01 0.98 W1 5995403.03 N 475162.86 E 0.000 1815.38 3400.00 53.336 326.158 2506.94 2563.04 1511l~ N ;\'1ì,~~~:~~ ~ 5995469.80 N 475118.40 E 0.000 1895.60 3476.00 53.336 326.158 2552.32 2608.42 lº~5!.t N 5995520.54 N 475084.61 E 0.000 1956.56 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3476.00ft MD, 2608.42ft TVD 9 5/8" Casing 3500.00 53.336 326.158 2566.65 2622.75 1641.07 N 1100.33 W 5995536.57 N 475073.94 E 0.000 1975.81 3575.94 53.336 326.158 2612.00 2668.10 1691.66 N 1134.25 W 5995587.27 N 475040.18 E 0.000 2036.72 C-80 (K-10) 3600.00 53.336 326.158 2626.37 2682.47 1707.69 N 1145.00 W 5995603.34 N 475029.48 E 0.000 2056.02 3700.00 53.336 326.158 2686.08 2742.18 1774.32 N 1189.67 W 5995670.10 N 474985.02 E 0.000 2136.24 3800.00 53.336 326.158 2745.79 2801 .89 1840.94 N 1234.34 W 5995736.87 N 474940.56 E 0.000 2216.45 ~. 3900.00 53.336 326.158 2805.50 2861 .60 1907.57 N 1279.01 W 5995803.64 N 474896.11 E 0.000 2296.67 4000.00 53.336·'·.. 326.158. 2865.22 2921 .32 1974.19 N 1323.68 W 5995870.40 N 474851.65 E 0.000 2376.88 4100.00 . 53.336' 326.1QQ . 2924.93 2981.03 2040.82 N 1368.35 W 5995937.17 N 474807.19 E 0.000 2457.10 4200.00 53.336 326.158 2984.64 3040.74 2107.44 N 1413.03 W 5996003.94 N 474762.73 E 0.000 2537.31 4300.00 53.336 326.158 3044.35 3100.45 2174.07 N 1457.70 W 5996070.70 N 474718.27 E 0.000 2617.53 4400.00 53.336 326.158 3104.07 3160.17 2240.69 N 1502.37 W 5996137.47 N 474673.81 E 0.000 2697.74 4500.00 53.336 326.158 3163.78 3219.88 2307.32 N 1547.04 W 5996204.24 N 474629.35 E 0.000 2777.96 .- 4600.00 53.336 326.158 3223.49 3279.59 2373.94 N 1591.71 W 5996271.00 N 474584.89 E 0.000 2858.17 4700.00 53.336 326.158 3283.20 3339.30 2440.57 N 1636.38 W 5996337.77 N 474540.44 E 0.000 2938.39 4800.00 53.336 326.158 3342.92 3399.02 2507.19 N 1681.06 W 5996404.54 N 474495.98 E 0.000 3018.60 4900.00 53.336 326.158 3402.63 3458.73 2573.82 N 1725.73 W 5996471.31 N 474451.52 E 0.000 3098.82 5000.00 53.336 326.158 3462.34 3518.44 2640.44 N 1770.40 W 5996538.07 N 474407.06 E 0.000 3179.03 5100.00 53.336 326.158 3522.06 3578.16 2707.07 N 1815.07 W 5996604.84 N 474362.60 E 0.000 3259.25 5200.00 53.336 326.158 3581.77 3637.87 2773.69 N 1859.74 W 5996671.61 N 474318.14 E 0.000 3339.46 5300.00 53.336 326.158 3641 .48 3697.58 2840.32 N 1904.41 W 5996738.37 N 474273.68 E 0.000 3419.68 DrillQuest 3.03.02.005 Page 4 of7 O - 'G ',ñ-' l L . ~ /i'\ .. -';; ,.' .I \ ,Ii 1¡iVÞ\ 18 December, 2002 - 11:33 Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target wI 10° Inc. Revised: 16 September, 2002 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin~š¡¡I:, Râm Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 5400.00 53.336 326.158 3701.19 3757.29 2906.94 N 1949.08 W 5996805.14 N 3499.89 5500.00 53.336 326.158 3760.91 3817.01 2973.57 N 1993.76 W 59968Z.l~91 N 0.000 3580.11 5600.00 53.336 326.158 3820.62 3876.72 3040.19 N 2038.43 W 59J~,Qfq§1 N 0.000 3660.32 5700.00 53.336 326.158 3880.33 3936.43 3106.82 N 2083.10 W _____ 591ló05:BN 0.000 3740.54 ..-.".".,,;.:.-.,.,:",:--. ':~'.:';'::::::::::;'. '~::::::::;:;::::.:" 5800.00 53.336 326.158 3940.04 3996.14 3173.44 N w,¡mií¡IgíÍ'â99ñQZ2.2~;N 0.000 3820.75 5900.00 53.336 326.158 3999.76 4055.86 3240.07 N ,,:1[,.'1'38.97 N 474006.93 E 0.000 3900.96 "- 5947.30 53.336 326.158 4028.00 4084.10 3271.58 N '¡I¡¡H¡õ997170.56 N 473985.90 E 0.000 3938.91 C-40 (K-3) 5954.80 53.336 326.158 4032.48 4088.58 32Zß,58 N 5997175.57 N 473982.56 E 0.000 3944.93 Begin Drop @ 2.0o/100ft : 5954.80ft MD, 4088.58ft TVD 6000.00 52.432 326.158 4059.75 4115.85 ~.õ~la¡N com1"216.99 W 5997205.56 N 473962.59 E 2.000 3980.97 6100.00 50.432 326.158 4122.09 4178.19 ~i71.4~¡N 2260.53 W 5997270.64 N 473919.26 E 2.000 4059.15 -,-~;:::::::::::::::>. J'..:' 6200.00 48.432 326.158 41 87.13 4243.23 3.¡~! N 2302.83 W 5997333.86 N 473877.16 E 2.000 4135.11 6300.00 46.432 326.158 4254.77 4310.87 . 8495.71 N 2343.85 W 5997395.16 N 473836.34 E 2.000 4208.75 6400.00 44.432 326.158 4324.94 4381.04 3554.88 N 2383.52 W 5997454.46 N 473796.86 E 2.000 4279.99 6500.00 42.432 326.158 4397.56 4453.66 3611.97 N 2421.80 W 5997511.68 N 473758.75 E 2.000 4348.73 6600.00 40 .432 326.158 4472.53 4528.63 3666.93 N 2458.65 W 5997566.75 N 473722.08 E 2.000 4414.90 6700.00 38.432 326.t58. 4549.76' 4605.86 3719.69 N 2494.02 W 5997619.62 N 473686.88 E 2.000 4478.42 6800.00 36.432 326.158 -- '... 4629.17 4685.27 3770.17 N 2527.87 W 5997670.21 N 473653.19 E 2.000 4539.20 6900.00 34.432 326.158 4710.64 4766.74 3818.32 N 2560.15 W 5997718.46 N 473621.06 E 2.000 4597.17 7000.00 32.432 3g6.198 4794.09 4850.19 3864.07 N 2590.83 W 5997764.31 N 473590.53 E 2.000 4652.26 7100.00 30.432 326.15Q 4879.41 4935.51 3907.39 N 2619.87 W 5997807.72 N 473561.63 E 2.000 4704.40 7200.00 28.432 326.158 4966.50 5022.60 3948.20 N 2647.24 W 5997848.62 N 473534.39 E 2.000 4753.54 7300.00 26.432 326.158 5055.26 5111.36 3986.46 N 2672.89 W 5997886.96 N 473508.86 E 2.000 4799.61 7392.79 24.576 326.158 5139.00 5195.10 4019.64 N 2695.14 W 5997920.21 N 473486.72 E 2.000 4839.56 Top Morraine "- 7400.00 24.432 326.158 5145.56 5201.66 4022.13 N 2696.81 W 5997922.70 N 473485.06 E 2.000 4842.55 7500.00 22.432 326.158 5237.31 5293.41 4055.15 N 2718.95 W 5997955.80 N 473463.02 E 2.000 4882.31 7600.00 20.432 326.158 5330.39 5386.49 4085.50 N 2739.30 W 5997986.21 N 473442.77 E 2.000 4918.85 7700.00 18.432 326.158 5424.69 5480.79 4113.13 N 2757.83 W 5998013.90 N 473424.33 E 2.000 4952.12 7758.11 17.270 326.158 5480.00 5536.10 4127.93 N 2767.75 W 5998028.73 N 473414.46 E 2.000 4969.93 Top H RZ 7800.00 16.432 326.158 5520.09 5576.19 4138.01 N 2774.51 W 5998038.84 N 473407.73 E 2.000 4982.07 7900.00 14.432 326.158 5616.48 5672.58 4160.11 N 2789.33 W 5998060.98 N 473392.98 E 2.000 5008.68 DrillQuest 3.03.02.005 .~ Total Depth: 8347.00ft MD, 6111.09ft TVD (1708' FSL & 876' FWL, SEC. 7- T12N-R8E) 7" Casing Miluveach TARGET: Start Sail @ 10.0° : 8121.5~ MD, 5889.10ftTVD (1675' FSL :8 FWL, See 7-T12N-R8E) ~ Kuparuk Target - 3S-15 (Goo), 150.00 Radius., Current Target Base HRZ 5059.96 5069.17 5086.54 5094.70 0.000 0.000 0.000 0.000 C ~(eG5 ~~~~! It / -.' ~ll~\·L1. , ,,1 ~r¡,_ 18 December, 2002 - 11:33 Based upon Minimum Curvature type calculations, at a Measured Depth of 8347.00ft., The Bottom Hole Displacement is 5094.70ft., in the Direction of 326.158° (True). The Dogleg Severity is ifl Degrees pëf1 00 feet (US). Vertical Section isffom 2524' FNL. 1091' FEL and calculated along an Azimuth of 326.158° (True). Magnetic DecJination at Surface is 25.4500(16-Sep-02) All data is in Feet (US) unless otherWi~e:.~tå!~. Dirêêtiåns and coordinates are relative to True North. Vertical depths are relative to RK~'= 56.1' M$:L. Northings and Eastings are relative to 2524' FNL. 1091' FEL. Global Northings and Eéi$tinQS ~rer~l~é to NAD27 Alaska State Planes. Zone 4. 473364.56 E 473359.45 E 473349.83 E 473345.31 E 5998103.67 N 5998111.33 N 5998125.79 N 5998132.58 N 2817.89 W 2823.01 W 2832.68 W 2837.23 W 8146.98 10.000 326.158 5858.00 5914.10 8200.00 10.000 326.158 5910.22 5966.32 8300.00 10.000 326.158 6008.70 6064.80 8347.00 10.000 326.158 6054.99 ,.,:6111.09 Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7939.70 13.638 326.158 5655.00 5711.10 4168.11 N 2794.69 W 5998069.00 N 473387.{?4 E 5018.31 8000.00 12.432 326.158 5713.74 5769.84 4179.40 N 2802.26 W 599808Q.32 N ;;;;f!73380.11 E 2.000 5031.91 8050.35 11 .425 326.158 5763.00 5819.10 4188.05 N 2808.06 W 5998088.98 N 'fi{'1~37 4.34 E 2.000 5042.31 8100.00 10.432 326.158 5811.75 5867.85 4195.87 N 2813.30 W 5998096.81 N 4~9.12 E 2.000 5051.73 8121.59 10.000 326.158 5833.00 5889.10 4199.05 N 28tªi~ w';m1/\1:§ß9~aÁ10.OQ..N 473367.00 E 2.000 5055.55 K-1 Comment ConocoPhillips Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target wI 10° Inc. Revised: 16 September, 2002 DrillQuest 3.03.02.005 Page 6 of 7 .... :¡ · '~.'." Il\. .f, ._ .".".. , w, I {J ! ¡ iJ ;, 1 ._ 18 December, 2002 - 11:33 Formation TO/JS Measured Vertical Sltþ-$~a Depth Depth ; 'Qepth-.··.-·- Northings Eastings Dip Up-Dip Formation Name (ft) (ft) ,<m (ft) (ft) Angle Dirn. 1700.14 1546.10 ' 1490.00 443.15 N 297.13 W 0.000 359.817 8. Permafrost 2475.67 2011.10- 1955.00 958.61 N 642.74 W 0.000 359.817 T. West Sak 3220.91 2456.10 2400.00 1455.12 N 975.65 W 0.000 359.817 B. West Sak 3575.94, 2668.10 2612.00 1691.66 N 1134.25 W 0.000 359.817 C-80 (K-10) 5947.30 4084.10 4028.00 3271 .58 N 2193.57 W 0.000 359.817 C-40 (K-3) ~' 7392.79 5195.10 5139.00 4019.64 N 2695.14 W 0.000 359.817 Top Morraine 7758.11 5536.10 5480.00 4127.93 N 2767.75 W 0.000 359.817 Top HRZ 7939.70 5711.10 5655.00 4168.11 N 2794.69 W 0.000 359.817 Base HRZ 8050.35 5819.10 5763.00 4188.05 N 2808.06 W 0.000 359.817 K-1 8121.59 5889.10 5833.00 4199.05 N 2815.43 W 0.000 359.817 Kuparuk SHL (2524' FNL & 1091' FEL, SEC. 18- Tf2N - R8E) Begin Dir @ 2.cr'/10Oft (in 12-1/4H Hole): 200.00ft MD, 200.00ft TVD Increase in Dir Rate @ 4.0°/1000: 700.000 MD, 697.47ft TVD End Dir, Start Sail @ 53.34° : 1783.39ft MD, 1597.72ft TVD '8" Csg ~!~~i~rill out 8:1/2" Hole: 3476.00ft MD, 2608.42ft TVD rop @'i2:00/1OOft : 5954.80ft MD, 4088.58ft TVD [: Start Sail @ 10.0° : 8121.500 MD, 5889.1 Oft TVD (1675' FSL & 898' FWL, See 7-T12N-R8E) pth : 8347.00ft MD, 6111.09ft TVD (1708' FSL & 876' FWL, SEC. 7-T12N-R8E) ---,' ConocoPhillips 0.00 E 0.00 E 24.24 W 333.49 W 1089.60 W 0.00 O.OON 200.00 O.OON 697.47 36.15 N 1597.72 497.38 N 2608.42 1625.08 N 4088.58 3276.58 N 5889.10 4199.05 N 6111.09 4231.56 N 5954.80 8121.59 8347.00 0.00 200.00 700.00 1783.39 3476.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target w/10Ø Inc. Revised: 16 September, 2002 Comments Western North Slope Western North Slope Formation Toos (Continued) Measured Depth (ft) Vertical De pth (ft) Sub-Sea Depth (ft) 8146.98 5914.10 5858.00 Casina details From Measured Vertical Depth Depth (ft) (ft) Northings (ft) 4202.71 N To Measured Vertical Depth Depth (ft) ( <Surlace> <Surlace> <Surlace> <Surlace> 3476.00 8347.00 f-:-;:, :':"~ - -----::. Taraets associatedwithtthiŠ?welloath Target Narne 3S-15 (Geo) 18 December, 2002 -11:33 Sperry-Sun Drilling Services Proposal Report for 35-15 Plan - 35-15 (wp03) Your Ref: Intersect Target wI 100 Inc. Revised: 16 September, 2002 Eastings Dip Up-Dip FormatiQnName (ft) Angle Dirn. 2817.89 W 0.000 359.817 Miluveach 9 5/8" Casing 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 5889.10 4199.05 N 2815.43 W 5833.00 5998100.00 N 473367.00 E 700 24' 21.2884" N 2090 46' 59.4615" E Circle 1 50.000 Page 70f7 f 1 I r j;\ ...A L.' L. 1 Ii ~,-·A i'! .,' L ConocoPhillips _/ Target Type Current Target "-/' DrillQuest 3.03.02.005 ') , " '~pØh··II· Conoco . . I. Ips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 38-15 (wp03) ".~ , ~~k~ ~,'?F'.,'~ ¡ Reference is True North Well: Current Well Properties 3S·15 Plan Hortzontal Coordlnata.: Rat. Global Coordlnata. : Rat. Structure: Ret. Geographical Coordinate. : 5993892.00 N, 478189,03 E 48.09 N, 286.12 W 70" 23' 39.9926' N, 209" 48~ 21 ,9736' E 2524' FNL & 1091' FEL, SEC. 18· T12N ' R8E 56.10n above Mean Sea Level True North Feet (US) RKB Elevation: North Re'erence : Unit. : ) spe.........y-5UI! ~tEU,':b!~t!:tl.:,:~@:gB~\!Jj;;~"~~ A Halliburton Company 4þ o :()A ~;) 5400 I o 900 1800 2700 3600 4500 , I I I I I ¡ ('I r "'~,> l' '··ll! S. ]"'1' Fe' .'·'CC n T1 "" '''iiJE Scale: 1 inch = 900ft I " \.,") "l.. t¿.:.')¡~·.'· ;' ~" . d~) ¡.;;;L~ ()¡;;; .1, ?..... .t..i\i Yo ¡ ,,,,j o --1,¿'~_ --------- ---- --- ---- ------- (} Begin Dir @ 2.00/100ft (in 12-1/4" Hole): 200.00ft MD, 200.00ft TVD 900- ~ :/ I Increase in Dir Rate @ 4.00/100ft : 700.00ft MD, 697.47ft TVD \ "' End Dir, Start Sail @ 53.34° : 1783.39ft MD, 1597.72ft TVD / 1800 - ::J' en :::ã: 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: / 3476.00ft MD, 2608.42ft TVD T- ~ 2700 - II II) ~ £S. J:: ã. Q) I:) ~ 3600 - t Q) > 4500 - TARCET: Start Sail @ 10.0'·: 8121.b9ft rvm, b889.10ft TVD [·¡t';75' FSL & 89ß' FWL See 7·T12!'J-RSE} -== o o Q) II J::. o .£ 5400 - 3,"'..15 {(j(,o-Tn.r?t~1i "" Cin·//:. Radius: /SU.O(¡jf :¡,';W) }II T\,'fI. 411¡'111~ ,\' '.~};;;.¡~ W ~, å) ëti o CI) Total Depth: 8347,OOft MD, 6111.09ft TVD (1708' FSL & 876' FWL, SEC. 7-T12N-R8E) 6300 - o I 900 I 1800 I 3600 I 2700 Drill Quest 3.03.02.005 C ~ 11'" :,~ :"~~",,¡f. , " ~,ì" ! il¡ L1lr/;. Begin Drop @ 2.00/100ft : 5954.80ft MD, 4088.58ft TVD / " \ , , \ ". ", ~ --~ I 4500 - 900 - 1800 ::J' en :::ã: - 2700 ..- <Ó LO II II) ~ ES J:: ã. Q) I:) ëti u t: Q) > - 3600 - 4500 - 5400 -== o o Q) II J::. o .£ Qj ëti o CI) - 6300 Scale: 1 inch = 900ft I 5400 ,) ConocJ'PhUlips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 35-15 (wp03) ",:1:1", i*': ., . ~ Reference is True North Well: Current Well Properties 3S·15 Plen Horizontal Coordinates: ReI. Global Coordinates: Ret. Structure: ReI, Geographical Coordinate. : ) 5¡pal'l'\I-5UI1 çfFi'1 i..'CTN ~::.§;§!fB:\llç;J!t§ A Halliburton Compan)' RKB Elevation: North R.terence : Units: 5993892,00 N. 476169.03 E ~;0~3~3~,~~~~' ~, 209" 48' 21 ,9736" E 2524' FNL & 1091' FEL, SEC. 18· T12N· R8E 56,10n above Mean Sea Level T rue North Feet (US) -3500 I -2800 I -2100 I -1400 I Tolal Deplh : 8347.0011 MD, 6111.0911 TVD (1708' FSL & 876' FWL, SEC. 7-T12N-R8E) 4200 - 4øO.ø() ~O ~ 0 <:>A) I ~ j #) I j I - 4200 I i I I - 3500 I I I I - 2800 I I I en C) I c:: I :.ë - 2100 t 0 Z I i I - 1400 g 0 I "- II .!: () ,S I I Q) (ij () (J) - 700 -700 I TAfiGET: Start Saii ii~ 10,0" : 13121 ,GOft MD, 5HH8,lOft 1VD (1i:mi' FBL. & 85,1!)' r:Wl" r"SG ,?,T'I;::N,H},1E) 3500 - 3S·/S IGIIO^'líüget) Cird,>, Radiu.>; f5(¡,()I)jt 5889.10 1-¡iO" 4.19;J,fJ5 ,V, 2SIS.43 W Begin Drop @ 2.0°/10011 : 5954.8011 MD, 4088.5811 TVD 2800 - en C) c:: :.ë 15 2100- Z 9-5/8" Csg PI... Drill oul 8-1/2" Hole: 3476.0011 MD, 2608.4211 TVD .:t:: o o "- II .!: () .S Q) (ij () (J) 1400 - End Dir, Slart Sail @ 53.34° : 1783.3911 MD. 1597.7211 TVD 700 - Increase in Dir Rale @ 4.0°/1000: 700.0011 MD. 697.4711 TVD <1>"1- "'I.~' 9-5/8' Csg Pt. MD: 3476,0011 TVD: 2608,4211 o Begin Dir @ 2.0°/10011 (in 12-1/4' Hole): 2oo.00ft MD, 2oo.00ft TVD --------------------- I I o SHL ::;.~¿;::.~' Ft~L$.. ~ }~¡ ¡::ç:' ~:t:.:\~,. 1B· r~~:N· H~E':¡ -3500 -2100 -1400 -700 -2800 Scale: 1 inch = 700ft Ea~n~ . G J 7~.,~ -'1 . .....1 ~¡~h_ DrillQuesl 3.03.02.005 ---0 ConocoPhillips Alaska, Inc. 35...15 (wp03) MD Inc Azim. SSTVD TVD N/S E/W y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) C /100ft) (ft) 0.00 0.00 0.00 -56.10 0.00 0,00 N 0,00 E 5993892.00 N 476169.03 E 0.00 0,00 SHL -- 200.00 0.00 0.00 143.90 200.00 0.00 N 0.00 E 5993892.00 N 476169.03 E 0.00 0.00 Begin Dir @ 2.0o/100ft (in 12-114" Hole) 700.00 10.00 326.16 641 .37 697.47 36.15 N 24.24 W 5993928.23 N 476144.91 E 2.00 43.52 Increase in Dir Rate @ 4.00/10aft 1700.14 50.01 326.16 1490.00 1546.10 443.15 N 297.13 W 5994336.09 N 475873.32 E 4.00 533.54 B. Permafrost 1783.39 53.34 326.16 1541 .63 1597.73 497.38 N 333.49 W 5994390.44 N 475837.13 E 4.00 598.84 End Dir; Start Sail 2475.67 53.34 326.16 1955.00 2011.10 958.61 N 642.74 W 5994852.65 N 475529.35 E 0.00 1154.14 T. West Sak 3220.91 53.34 326.16 2400.00 2456.10 1455.12 N 975.65 W 5995350.23 N 475198.02 E 0.00 1751.93 B. West Sak 3476.00 53.34 326.16 2552.32 2608.42 1625.08 N 1089.61 W 5995520.54 N 475084.61 E 0.00 1956.56 9-5/8" Csg Pt ... Drill out 8-112" Hole 3575.94 53.34 326.16 2612.00 2668.10 1691.66 N 1134.25 W 5995587.27 N 475040.18 E 0.00 2036.72 C-80 (K-10) 5947.30 53.34 326.16 4028.00 4084.10 3271.58 N 2193,57 W 5997170.56 N 473985.90 E 0.00 3938.91 C-40 (K-3) 5954.81 53.34 326.16 4032.48 4088.58 3276.58 N 2196.92 W 5997175.57 N 473982.56 E 0.00 3944.93 Begin Drop @ 2.00/100ft 7392.79 24.58 326.16 5139.00 5195.10 4019.64 N 2695.14 W 5997920.21 N 473486.72 E 2.00 4839.56 Top Morraine 7758.11 17.27 326.16 5480.00 5536.10 4127.93 N 2767.75 W 5998028.73 N 473414.46 E 2.00 4969.93 Top H RZ 7939.71 13.64 326.16 5655.00 5711 .10 4168.11 N 2794.69 W 5998069.00 N 473387.64 E 2.00 5018.31 Base HRZ 8050.35 11 .43 326.16 5763.00 581 9.1 0 4188.05 N 2808.06 W 5998088.98 N 473374.34 E 2.00 5042.31 K-1 8121.59 10.00 326.16 5833.00 5889.10 4199.05 N 2815.43 'IN 5998100.00 N 473367.00 E 2.00 5055.56 TARGET: Start Sail @ 10.0° 8146.98 10.00 326.16 5858.00 5914.10 4202.71 N 2817.89 W 5998103.67 N 473364.56 E 0.00 5059.96 Miluveach 8347.00 10.00 326.16 6054.99 6111 .09 4231.56 N 2837.23 W 5998132.58 N 473345.31 E 0.00 5094.70 Total Depth .~ ,n~/~~"~'~' 'J f¡¡.~., , ..~ Sperry-Sun Drilling Services Proposal Data - 35-15 Plan - 35-15 (wp03) / MD Delta Inclin. I Azimuth I TVD Northings ¡ Eastings Dogleg! Toolface ! VS (326") I (~.oo MD (ft), ~~~òôl u ~oo/ -(~oo -- (~.od (ft) 0.oo_(OI100ft~l~_~ (ft) 0.00 I -. .." - - -- - - -, - I. __. _. ... _ _. _ _ _ _ _ ______. __.,,____ _ __ _ ___ _·__.___n_______ ____1' _______________. ____ 200.00 200.00: 0.000 0.000 200.00' 0.00 0.00: 0.000 0.000 0.001 ---700.00["- - -500'-00[ -1Õ~OOO---326-.158-----697~4-7-;- - --36~15N--24-:24ï;.j; ----- 2.000 326.158 43.521 1783.39 1083.39 53.336 326.158 1597.73 497.38 N 333.49 W 4.000 0.001 - -- -598.841 5954.80 4171.41 53.336 326.158 4088.58 3276.58N 2196.92W 0.000 0.000 3944.931 ! 8121.59 2166.79 10.000 326.158 5889.10 4199.05N 2815.43W 2.000 180.000 5055.55! 8347.00 225.41 1O-"_00~__~~_~~1_?~__ __~~11.09__~~~._~~_~' 2837.23 W 0.009__~.~oj ______509~ 1 2 3 4 5 6T 7 18 December, 2002 - 11 :32 -- --.-/ 0: - ] VA:.. DrillQuest Sperry-Sun Drilling Services Proposal Data - 35-15 Plan - 35-15 (wp03) I II MD Delta Inclin. Azimuth TVD Northings i (ft) M 0 (ft) (0) (0) (ft) (ft) ~-- ---~,-- ~-- - .--... ---.-. ..- -- ~- -.-. -. _.,---- _..---------- ---:---- 1 0.00: 0.000: 0.000 -56.10! 5993892.00 N -- --- - .---- ,--~---. -,... -. -. ,- - --~ ..~.-~,----------- ---"r 2 200.00: 200.00; 0.000; 0.000 143.90; 5993892.00 N -3-- . 7oo.ocf-50iioor10:00Ör'326.34-1--S41.3ir-5993928.23 N 4 1783.39 1083.39 53.336 326.341 1541.63 5994390.44 N 5 5954.80 4171.41 53.336 326.341 4032.48 5997175.57 N 6T 8121.59 2166.79 10.000 326.341 5833.00 5998100.00 N 7 8347.00 225.41_._ _~~~~ln~~?:~41__6054.99 5998132.58 N: 18 December, 2002 - 11 :32 Eastings (ft) 476169.03 E 476169.03 E 476144.91 E 475837.13 E 473982.56 E 473367.00 E 473345.31 E: i I Dogleg I Toolface . VS (326°) . (°/1 DOft) (0) (ft) 0.00' 0.00 43.52 598.84 3944.93 : 5055.55 5094.70, 0.000: 2.000: 4.000 0.000 2.000 0.000: 0.000 326.341 0.001 0.000 180.000 0.000 [ - 1 - ,-,,' --' J .. 'I G- J~ ¡ l -.' 1 i i\;¡J~~ DriJJQuest Company: Field: Refel'ence Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. KuparukRiver Unit Kuparuk3S Pad Plan:3S-15 Plan: 3S-15 )SPERRY_SUN RES ') Anticollision Report Date: 12/18/2002 Page: Time: 13:42:48 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: 3S-15, True North RKB= 55.8'MSL 55.8 GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.10 to 8347.00 ft Maximum Radius: 1031.89 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 5/15/2002 Validated: No Planned From To Survey ft ft 28.10 499.70 499.70 8347.00 Casing Points MD ft 3475.70 8347.00 Planned: 3S-15 (wp03) V5 Planned: 3S-15 (wp03) V5 TVD ft 2608.09 6110.64 Diameter in 9.625 7.000 Hole Size in Name 12.250 8.500 95/8" 7" Summary <--~---------_·_-----·-Offset Wellpath' -~._--~~--~_._------~-> Site Well Wellpath Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad 3S-07 3S-18 3S-26 3S-26 Plan: 3S-03 Plan: 3S-06 Plan: 3S-06 Plan: 3S-08 Plan: 3S-08 Plan: 3S-09 Plan: 3S-09 Plan: 3S-10 Plan: 3S-10 Plan: 3S-14 Plan: 3S-16 Plan: 3S-17 Plan: 3S-17 Plan: 3S-19 Plan: 3S-19 Plan: 3S-20 Plan: 3S-21 Plan: 3S-21 Plan: 3S-22 Plan: 3S-23 Plan: 3S-24 3S-07 V5 3S-18 V4 3S-26 V2 3S-26A V3 Plan: 3S-03 V2 Plan: 3 Plan: 3S-06 V2 Plan: 3 Plan: 3S-06F V2 Plan: Plan: 3S-08 V2 Plan: 3 Plan: 3S-08F V2 Plan: 3S-09 (Surveys) VO Plan: 3S-09 V1 Plan: 3 Plan: 3S-10 V2 Plan: 3 Plan: 3S-10F V3 Plan: Plan: 3S-14 V1 Plan: 3 Plan: 3S-16 V1 Plan: 3 Plan: 3S-17 VO Plan: 3 Plan: 3S-17F V1 Plan: Plan 3S-19F V2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Plan: 3S-20 V1 Plan: 3 Plan: 3S-21 V1 Plan: 3 Plan: 3S-21 F V2 Plan: Plan: 3S-22 V2 Plan: 3 Plan: 3S-23 V1 Plan: 3 Plan: 3S-24 V1 Plan: 3 Version: Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MW D - Standard Reference Offset Ctr-Ctr 'No~Go Allowable MD MD Distance, Area Deviation WarninV ft ft ft ft ft 248.98 250.00 160.43 4.56 155.87 Pass: Major Risk 250.35 250.00 61.41 4.55 56.85 Pass: Major Risk 852.43 850.00 198.02 13.60 184.42 Pass: Major Risk 852.43 850.00 198.02 13.60 184.42 Pass: Major Risk 676.76 700.00 229.30 11.31 218.03 Pass: Major Risk 248.91 250.00 180.63 5.14 175.49 Pass: Major Risk 248.91 250.00 180.63 5.14 175.49 Pass: Major Risk 249.15 250.00 140.63 5.21 135.42 Pass: Major Risk 249.15 250.00 140.63 5.21 135.42 Pass: Major Risk 199.99 200.00 121.03 3.81 117.22 Pass: Major Risk 249.27 250.00 120.57 5.36 115.21 Pass: Major Risk 249.39 250.00 100.34 5.38 94.96 Pass: Major Risk 249.39 250.00 100.34 5.38 94.96 Pass: Major Risk 349.62 350.00 21.59 7.52 14.07 Pass: Major Risk 449.98 450.00 19.20 9.43 9.77 Pass: Major Risk 350.72 350.00 41.40 7.21 34.20 Pass: Major Risk 350.72 350.00 41 .40 7.21 34.20 Pass: Major Risk 300.98 300.00 80.99 6.13 74.86 Pass: Major Risk 300.98 300.00 80.99 6.13 74.86 Pass: Major Risk 301.16 300.00 100.70 5.84 94.85 Pass: Major Risk 352.15 350.00 120.17 7.14 113.03 Pass: Major Risk 352.15 350.00 120.17 7.14 113.03 Pass: Major Risk 301.69 300.00 140.20 5.95 134.26 Pass: Major Risk 403.83 400.00 160.82 8.16 152.66 Pass: Major Risk 302.25 300.00 181.08 6.14 174.94 Pass: Major Risk C i J r\ , ~ , ~'! .f' ~ ~U,' j U II vi :.. WElLP A 111 DErAILS Pbn: 3S-15 Ri2: N7ES Ref. Datull: RKB = 55.8" MSL 55.8011 V.Sectim Origin Origin Starting Angle +NI-S +F1-W From TVD 326.35 0.00 0.00 0.00 COMPANY DErAILS P~s Ah.sb Inc. Engi1..rng Kuparuk CakuhtDn Method: MI1ÌI1Um Cun= Error Splem: ISCWSA Scan Method: Trav Cylilder North Error Surface: Elliptic.1+ Casing Wamßg ~iethod: RuJcs Based ANTI-COLLISION SETI1NGS Interpolation Method:MD Interval: 50.00 Depth Range From: 28.10 To: 8347.00 Maximum Range: 1031.89 Reference: Plan: 3S-l5 Sbl NlA Longìude 150'11'38.028W l.atitudc 0'23'39.'I93N IJEr^II_~ Ea...ting 4761611.97 WI ~Irth"'~ .'i9931!'12,07 +F.I-W -21!6.21 +NI-S 4X.17 Name Pbn:.' (wp03) From Colour To MD o 200 200 400 400 - 600 600 - 800 800 - 1000 1000 1500 1500 - 2000 2DOO 25DO 2500 - 3000 3DOO - 3SDO 3500 - 40DO 4000 4SDO 4500 - 5000 5000 - 55 DO 5500 6000 6DOO - 70DO 7000 - 80DO 8000 - 9000 Tool CB-GYRO-SS MWD SURVEY PROGRAM 5/15/2002 Validaled: No Version: Date SurveylPlan Planned: 3S-15 (wp03) V5 Planned: 3S-15 (wp03) V5 Depth To 499.70 8347.00 Depth Fro 28.10 499.70 tB .~, ~ - .' ,,/ Ii ~ . ,,};-- / '"""' -10 ,;'to" ,ll~J?'m--'&1~ ~-----'-_. II ~ ~\ /' Aft I~ ~ ,><~~ 1 ~ . ,,<:;,,\'0" . ~\~. ~~".,. see -" .". .~ TIUA'@)ETAtÏ§"26 CiS-26M +N/-S +E/-W D O.DO Leg 0.00 O.DO 0 00 36.15 0.00 0'00 497 SO -24.24 . 3276:70 2-333.56 ¡.gg 4199 39 - 197.DO . 423Ù8 -2815.65 g.gg -2837.43 0:00 Plan: 3S-14 (pI 90 ~ ~' o 4.\ 40 / ~ / / / ~ ~ / / (/(/~ ~ , f ) ~ \ ~~/J ) \ / 30 27[; -44 -40 -30 -20 -10 -20 -30 -40 -44 -0 o \\ \ -423 -400 -300 -200 -100 -0 270 -100 -200 -400 423 (Plan: 3S- I 6) 35-15 (wp03) --- Approved Plan Target 3S (15) VSec 0.00 0.00 43.52 598.97 3945.05 5055.94 5095.05 TFace 0.00 0.00 326.16 0.00 0.00 180.00 0.00 TVD 28.10 200.00 697.47 1597.82 4088.08 5888.80 6110.64 Azi 0.00 0.00 326.16 326.16 326.16 326.16 326.16 Ine 0.00 0.00 10.00 53.34 53.34 10.00 10.00 MD 28.10 200.00 700.00 1783.56 5954.62 8121.74 8347.00 See I 2 3 4 5 6 7 --- [deg] vs Centre to Centre Separation [20fúin] Travelling Cylinder Azimuth (TFO+AZI) INAL onlG Centre to Centre Separation [200fúin] [deg] vs Azimuth (TFO+AZI) Travelling Cylinder )) 35-15 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Event Risk Level M itiqation Strateqy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Gravel/Sand Sloughing to Moderate Increase mud weight / viscosity, High viscosity 500' sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill .// Trips (use of trip sheets), Pumping out of hole as needed. Possible thaw bulb / water flow Low Watch return viscosity for signs of thinning. around 1200' Increased mud weight/viscosity as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Sag Differential Sticking Low Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Moderate M itiqation Strateqy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. ,/ 35-15 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 -- r I f1 r~l '~t, f ìJ L~l G ~ :',{ /',;1 ' If ,I 1 9 i ':~ j; I,. Page 1 of 1 KRU - 35-15 Proc. _.'her Proposed Completion Schematic Single Completion wi Jet Pump Contingency 16"x30" insulated r I conductor @ ~ ~ +1-109' MD I I j ~ TAM 9-5/8" pOrtJj!.d Collar Stnd I Grade BTC ~ Threads (+/- , 1000' MDfTVD) ~ I ~ Surface csg. ~ 9-5/8"40# L-80 ....,¡L! BTC (3476' MD I 2608' TVO) Casing point 100' above the C80 sand C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L -80 BTCM (+/- 8347' MD) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ '" ~ ~ ~ ~ ~ ~ ~ ~ ~ ..J .........-~ j ~ -- .= ..: i ...,~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ þ~~~~ I ~ I ~ I I ~ I I ~ I L.... ~~ ~~ ~~ ~ I I I ~ I ~ 1 ~ z ~ I.... ~ -- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ / ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r- -iU. ,,-U. r-- ~ ~ ~ ~ ~ ~ ;; ~ ~ ~ ~ ') ,', ConocJPÍ1illips 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" 10 No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Valves #1--4: 3-%" x 1" KBUG Place gas-lift mandrels at the following depths: TVD Approximate MD GLM Placement TBD Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1- 100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-112", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. TD @ 8347' MO 16111' TVD (200' MD below Miluveach) Scott L Lowry 12/17102 Ji/G/NAL ) lody, We will provide you with a check in the amount of $100.00 for the Permit to Drill on 38- 15 when Sharon Allsup-Drake returns to the ConocoPhillips office January 6, 2003 fJ~~'7 ...., "'. . ~,. -' ,th' ...¿i . &'C:1tf T '""vVJ.Y~__u" ....u \.IUJ.!U J.J.J.,-,~sû.gc lÖ )'vu.. U_t-"__iFíc&lll.ll H-bcrdinc: 1C m~ll,- . ~ Thanks, ;£ ~at Godfrey 265-6995 ) 1 ~ - "' ·'-""·~1· . 1017 . 2fv 'i).. ce I ý? L'r)?- j DATE ).A ~ ~-14/311 t :;~~~~;';~E Síl+íG or AU1.<;fCl4/flc:Y!lC~ 1$ /O{,;'.¡)() ___ /L. L" ~ ~~ c1 ,f ;:~"C ,<-.-_ 7,'/, /I!'/A-¿;'~a>",_ t::J. ..""",r.,,,,,,, C/J.-I.f:.- t~"...~... tv tI/ w L( ßt , .., ...j/I /(e DOLLARS L!J ~:::::~'B"k, --.1 "..~I"1J·i'J1,~""~~.".~:øll\lllM,~ _ \''1_......4__.. _ .__ S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 ~ \ ~.. CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars , ., ,".~,.,..."_~.,~...oc,,'" ~ I ~ : 3S'~¡Ç -----'~L£.:j¡/Ll_~1J~41 I~M~ :~"~~~'~~':"~.?~'~':~""~'I~r:¡~~= ~~~9"'~~~1'~~"':"J?~':'=~'~¡~:r., ~"?""~IY 1?~~~~m~¡~'"'~"''',"I~'"~'''~~'''W~I'~~''' ~ ' ""., ,'~"r'~~~;r~;''''~1 . RECEIVED DEC 2 6 2002 AJaska Oil & Gas Cons. Commisslo.n Anchorage ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), 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). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\temp lates 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. (Company 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 ·C/'A WELL NAME I('<~, _ ~.S" -/¿;' PROGRAM:Exp _ Dev _ Redrll_ Re-Enter _Serv_ Wellbore seg_ FIELD & POOL ,<¡ 70/t>0 INIT CLASS /).,.._v l-A.~:/ GEOL AREA ? I A UNIT# /1/ ¡;~ ON/OFF SHORE ð,J 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. W ell 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 ,p/ .... / _ ) 8. If deviated, is wellbore plat included.. . . . . . . . . .'. . . . Y N ~ I~d<-., 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.. . . . . \)'l N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Y Y ,ILl.. .4, (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. X N ~ Û; to ; '. <Ø> 0 0 ( ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N ¡ )C 0 I·¡¡. 16. Surface casing protects all known USDWs. . . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y.&V 19. CMT will cover all known productive horizons. . . .' . . . . . . ~ N 20. Casing designs adequate for C~ T, B& permafrost. . . . . . . ,N, /J.ç r "7 E ' 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N !LI~ s S , 22. If a re-drill, has a 10-403 for abandonment been approved. . . .¥::1t- {U¡A- 23. Adequate wellbore separation proposed.. .',' . . . . . . . . . N 24. If diverter required, does 'it meet regulations. .. . . . . . . . N 1 25. Drilling fluid program schematic & equip list adequate. . . . . N (Yl JL/~ fY¿ /tJ I 2.., "3 f po¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N .fO A APPR DATE ~7. BOPE press rating appropriate; test to 5" 000 p sig. I N ¡VI, S ' 3' CJ 0 "5 P f. ¿ , ) 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 'ltJ6A- Il} 30/0 L-- 29. Work will occur without operation shutdown. . . . . . . . . . . N_ 30. 'Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y 4i!? 31. Mechanical condition of wells within AOR verified. . . . . . . . ~NIÆ- 32. Permit can b~ issued wlo hydrogen sulfide measures. . . . . cYN 33. Data presented on potential overpressure zones. . . . . . .. XN 34. Seismic analysis of shallow gas zones. . . . . . . .. .. .. .. .. .. Yy ~ /1/. 19 u 35. Seabed condition survey (ifoft-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RPr/f~ (Service Well Only) GEOLOGY APPR DATE ,,f/1/ W~~, (ExploraTo;Y Only) } UIC ENGINEER COMMISSIONER: Commentsllnstructions: TEM JDH JBR COT DTS () \ \ \Jî \ \) rv; MLB ol/~¿'/o3 Rev: 10/15/02 SFD WGA / MJW G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly gemlane to the Well Pennitting Process but is part of the history file. To inlprove the readability of the Well History file and to sinlplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chmnalogically organize this category of infonnation. '" '~ ) ) Q02-2Stf- , , 4>t.f'=> Sperry-Sun Drilling Services LIS Scan Utility $Revision: .3 $; LisLib $Revision: 4 $ Mon Jun 02 13:44:52 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0.3/ 06/ 02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin.. . .. . . . . . . . . . .. . . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wr:i.ting Library. Sci.entifie Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit Mlim/MAD LOGS ff WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: jl ,JOB DATA 3S-15 501032044400 Co no co Phillips Alaska, Inc. Sperry Sun 17-APR-03 JOB NUMGER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AI{-MW30003 P. SMITH D. BURLEY # SURFACE LOCATION SECTION: TOINNSHl P: RANGE: FNL: 1:'3L: FEL: FWL: E.LE:VATTON (F'T FROM MST. 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 '1 ;iN 8E 2524 1091 .00 56.65 ?7 . 70 if WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3562.U if RErv¡ARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). ::J. Hh'D RUN 1 WAS DIRECTIONAL ONLY AND IS NOT ~'RESENTED. ) ') 4. MWD RUNS 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4); STABILIZED LITHO-DENSITY (SLD); COMPENSATED THERMAL NEUTRON POROSITY (CTN); ACOUSTIC CALIPER (ACAL); BI-MODAL AC~)STIC TOOL (BAT); AND PRESSURE WHILE DRILLING (PWD). 5. HWD DATA l\RE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. G. MWD RUNS 1-2 REPRESENT WELL 3S-15 WITH API # 50-103-20444-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 8420' MD I 6209' TVD. SROP SGRC SEXP SESP SEMP SEDP SFXE SBD2 = SC02 SNP2 SHOOTHED RATE OF PENE'I'RATION WHILE DRILLING. SHOOTHED GAMMA RAY - GEIGER-HULLER TUBE DETECTORS SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) m100THED PHT\SE SIHFT DERIVED RESISTIVITY (SIIl\LLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUH SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SMOOTHED FORMATION EXPOSURE TIME SHOOTHED BULK DENSITY (LOW-COUNT BIN) SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOVIJ-COUNT BIN) SMOOTHED AVERl\GE OF Fl\R DETECTOR I S COUNT RATE SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SMOOTHED INTERVAL TRANSIT TIME OF COMPRESSIONAL WAVE, POST-WELL PROCESSED CTFA CTNA TNPS - DTCP PARAMETERS USED IN NEUTRON I POROSITY LOG CALCULATIONS: HOLE SIZE: 8.5" MUD WEIGHT: 9.4 - 12.4 PPG MUD FILTRATE SALINITY: 100 - 800 PPM CHLORIDE FORMATION WATEH. SALINITY: 25000 PPM CHLORIDE FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE FORMA'1'ION WATGR RESISTIVITY: 0.15 OHMM .$ File Header Service name............ .ST8LI8. 001 Service Sub Level Name.._ Version Number.......... .1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File Type....... ....... ..LO Pr'eviou~ F.i.1e Name....... STSLIB. 000 Comment Record FILE HEADER 1:'1 U: NUMBER: EDITED MERGED MWD Depth shi fted DE P'J'H 1 NCkr:MEN',j': ~ fILE SUMMARY PBU TOOL COOS DTC rEF NCNT FCNT E'ET RPD RPH Rrs RPX GR NPHI DRHO RHOS ROP 1 and clipped curves; all bit runs merged. .5000 ~ START UEI:"l'H 3500.0 3500.5 3500.5 3500.5 3533.0 :1s'n.o 3533.0 3533.0 3533.0 3540.5 3~56.5 3561.0 3561.0 J'JJ2.':> S'1'OI:' DE:I:''1'H (3306.5 8345.5 83?9.5 8329.5 8381.0 838] .n 8381.0 8381. (J 8381.Ci 8388.5 8333.0 8345.5 8345.5 ))420.0 ) ') II BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSI-II FTED DEPTH --------- BASELINE DEPTH $ it MERGED DATA SOUR,CE PBU TOOL CODE MWD BIT RUN NO MERGE TOP 2 3500.0 NERGE BASE 8420.0 $ # REHARKS: HERGED HAIN PASS. .$ Ii Data Format Specification Record Dat,a 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 Servi.ce Order Uni.,tc Si.ze Neam Rcp Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1. 68 4 2 GR ¡VIWD ]\PI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS ]v[wD OH¡V¡iV¡ 4 1 68 16 5 RPI"! MWD OHHM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1. 68 36 10 NCNT MWD CNTS /) 1. 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1. 68 52 111 DTC MWD USPF 4 1 68 .'.:>6 1.'.:> Fi.L'sL LasL Name Service Unit Min Hax Mean Nsam Rcad.i.ng Eeading DEPT FT 3500 8420 ~)960 9841 3500 8420 ROP ¡V¡vlJf) E'T I H 11.01 320.26 170.271 9696 3572.5 8420 GR MWD API 48.,16 113.86 122.165 9697 3540.5 8388.5 RPX MWD OHMM 0.78 1798.13 3.99241 9697 3533 8381 Rt='S MWD OHMM 0.77 2000 4.28769 9697 3533 8381 RPM MWD OUMM 0.77 2000 8.31507 9697 3533 8381 RPD MWD OHMM 0.62 2000 13.6208 9697 3533 8381 FET l'1WD HOUE 0.1628 106.609 1.47254 9697 3533 8381 NPHI MWD PU-S 9.61 bb.1'I 33.828 9bb4 3bb6.b 8333 E'CNT MWD CNTS 5% 2872.9 977.6;:,9 %59 3500.5 8329.5 NCNT MI^1O CNTS 115818 203810 139162 9659 3500.5 8329.5 RHOS MWD G/CM 1.994 3.13b :2.32231 %'/0 3b61 834.'.:>..'.:> DRHO ¡V¡WD G/CM -0.126 0.345 0.0542269 9570 3561 8345.5 PEE' MTtJD Bl\RN 1. 81 14.88 3.80366 9691 3500.5 8345.5 DTC MWD USPE' b1 138 110.939 9614 3bOO 8306.5 First RC.3ding For Entire File..........3500 Last Reading For Entire E'ile.......... .8420 File Trailer Service name.............STSLIB.OOl Service Sub Level N.3me... Version Number.......... .1.0.0 DaLe (-,[ Gerlet'al..iofl.......03/06/02 M.3ximum Phy~ic~l Rccord..G5535 ) File Type................ LO Next File Name...........STSLIB.002 Phys i céll EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 F i 1 e 'I' ype . . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY VENDOR TOOL CODE DTC PEF NCNT FCNT FET RPD RPM RPS RPX GR NPHI DRlrO RHOB ROP 2 ) header data for each bit run in separate files. 2 .5000 $ START DEPTH 3500.0 3500.5 3500.5 3500.5 3533.0 3533.0 3533.0 3533.0 3533.0 3540.5 3556.5 3561. 0 3561.0 3572.5 If LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DfULLSR (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLS: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR1 SLD CTN Bl\'l' $ #- STOP DEPTH 8306.5 8345.5 8329.5 8329.5 8381.0 8381.0 8381.0 8381.0 8381.0 8388.5 8333.0 8345.5 8345.,5 8120.0 BOTTOM) TOOL TYPE DUAL GAMÌ'1A RAY ELECTROMAG. RESIS. 1 STABILIZED LITHO DEN COMP THERMAL NEUTRON Bi-modal l\ccostic COREIIOLS l\ND Cl\SING Dl\Tl\ OPSN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS f"lUD TYPE: MUD DENSITY (LG/G): MUD VISCOSITY (S): 1'1UD PH: MUD CHLORIDES (PPM): l'I-~TAN - (Jj Insite 66.37 Memo t'Y 8420.0 3540.0 8420.0 8.9 55.6 TOOL NUMBER 155789 131758 1!:>1842 174114 166359 8.50(1 356=. ':' LSND 12.00 49.0 8.6 t:OU ) ) FLUID LOSS (C3): RESIS'l'IVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MA.,X CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 5.8 1.700 1.140 1. 550 2.100 81. 0 121.3 80.0 80.0 H NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): II TOOL STANDOFF (IN): EWR FREQUENCY (HZ): II REMARKS: $ H 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 Uni tE3 . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block :3ub-type... 0 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 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OI-IMM 4 1 68 16 5 RPM ~1WD02 0 OHM~1 1 1 68 20 6 RPD HWD020 OI-LMJv 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI tJIWD020 PU-S 4 1 68 32 9 rCNT MWD020 CNTS 4 1 68 36 10 N OfT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 GICM 4 1 68 44 12 DRHO MYI\TD020 G/CM 4 1 68 48 13 PEF JVIWD020 BA,RN 4 1 68 52 14 DTC MWD020 USPF 4 1 68 56 15 First. Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3500 8420 5960 9841 3500 8420 ROP MWD020 E'T / H 11.01 320.26 170.271 9696 3572.5 8420 GR MWD020 API 48.46 413.86 122.165 9697 :3540.5 8:38t\.5 RPX MWD020 OHHM 0.78 1798.13 3.99241 9697 3533 8381 RPS MWD020 OHMM 0.77 2000 1.28769 9697 3533 8381 RPM MWD020 o HHfvl O.n 2000 8.31::'0'/ 9 6 ')'I 3::'3::3 8381 RPD I'-lWD020 OHHH 0.62 2000 13.6208 9697 3533 8381 FeT MWD020 HOUR 0.1628 106.609 1.47254 9697 3533 8381 NPHI MWD020 pu-s 9.61 55.17 33.828 9.554 3556.5 8333 tCNT HWD020 CNTS 596 2872.9 977.659 9659 3500.5 8329.5 NCNT MWD020 CNTS 115818 203810 139162 9659 3500.5 8329.5 RHOB MII\TD020 G/8H 1.994 3.135 2.32231 9570 3561 8345.5 DRHO IV¡WD020 G / Cfv¡ -0.126 0.345 0.0542269 9570 3561 8345.5 pef Mt-JD020 Cl\RN 1. 81 14..88 3.80366 9691 3500.5 8345.5 DTC MWD020 USPF 51 138 110.939 9614 3500 83(16.5 first Re~ding For Entire File..........3500 Last Reading For Entire File.......... .8420 File Trailer Service Ild![\e.............STSLIB.002 Service Sub Level N~mc... ) ) Version Number.......... .1.0.0 Date of Generation.......03/06/02 Maximum Physical Recü.cd.. 65535 Fi 1 e Type................ 1,0 Next File Name......... ..STSLIB.003 Physicâl EOF Tape Trailer Service name............ .LISTPE Date.................... .03/06/02 Origin. . . . . . . . . . . . . . . . . . . srrs Tape Name................UNKNOWN Continuation Number...... 01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Heel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 06/ 02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......01 Next Reel Narne...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Lib,rary. Scienti fie Technical Services Physical EOF Physical E;OF E.nd Of: LIS File