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200-108
Imag~roject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are, available in the original file, may be§canned during a special rescan activity or are viewable by direct inspection of the file. <~ ~)~)- J 0~_ Well History File Identifier Organizing i~o,,~i [] RESCAN [~ Color items: [] Grayscale items: [] Poor Quality Originals: 1~ Other: NOTES: DIGITAL DATA Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL A~~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~Logs of Various kinds [] Other Sca~ningPreparation __,_~_x30= t~--~) + o~.~ = TOTALPAGES 173 BY: BEVERLY ROBIN VINCENT SHERYL(~)WINDY DATE: / Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~E FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON ~AL PAGE BASIS RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd F:\LaserFiche\CvrPgs _ I nserts\M icraft I m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE \ ) ) Petroleum Corporation Additional, Updated, or Replacement Information RECORD OF SHIPMENT DATE: September 23, 2002 TO: Mr. Steve McManns Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 FROM: Tommy Thompson Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, Alaska 99503 (907) 273-6302 (X) Enclosed ( ) Under separate cover ( ) Via Courier Subject: Well CompletionlRecompletion Report and Log APl: 50-283-20098-00 Permit Number: 200-108 Unit or Lease Name: Moquawkie ~Quantity Media Type Description Report Well Completion or Recompletion Report and Log CC: NOTE: Please verify and acknowledge receipt, by si~nin~l and returnin~ a copy of this transmittal to the above address or fax Date: 9/23/02 Remarks: STATE OF ALASKA ,r' ALASKA AND GAS CONSERVATIOI ,_'OMMISSION WELL COMPLETION OR RECOMPLETION REPORT .&ND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X sE/ ~~'~ Exploration 2. Name of Operator~'"~ .~? 7. Permit Number Anadarko Petroleum~ , 200-108 3. Address ID. '~:3~'. 8. APl Number 3201 C St., Ste 603, Anchorage AK, 99503 4.~~ 50- 283-20098-00 4. Location of well at suCace 1956 FNL & 199 FWL, Sec 30, T12N, R1 lW '~ .................. 9. Unit or Lease Name ,~ ~ ' "~': ~" i Moquawkie At Top Producing Inte~al ~ ~.~ 10. Well Number At Total Depth 1956 FNL & 199 ~L, Sec 30, T12N, RllW ~'~ ~Emc~.~ ~ 11 Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Lone Creek DF 412.9 GL 394.4I C061388 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 9-12-00 , 10-7-00 * 10-21-00 'I feet MSLI 0 ,7. Total Depth (MD+~D,,000 18. Plug Back Depth (MD+~D)su, I 10' Direoti°nal Su~ey I20' Depth where sssv setYes: No: X feet MD I21' Thickness °f Permafr°st 22. Type Electric or Other Logs Run G~Res/SP/RFT/Dip/CMR 23. CASING, LINER AND CEMENTING REcoRD SE~ING DEPTH MD CASING SIZE ~. PER FT. G~DE TOP BO~OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 92 X-56 SURF 92 DRIVEN N/A 13 3/8 68 L-80 SURF 244 17 1/2 196 E3 Id & 235 ~3 ti 9 5/8 40/47 L-80 SURF 998 12 1/4 188 E3 Id & 346 ~3 ti 7 26 L-80 SURF 2008 8 1/2 135 E3 Id & 101~3 ti 24. Pe¢orations open to Production (MD+~D of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NA NA 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1906' cmt ~nr 182 sx sqz below ~nr across 7" shoe Bal plug 909'-1100' 46 sx in 7" csg Bal plug 5'-170' 27 sx in 7" csg 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas li~, etc.) NA I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL ~TIO NA TEST PERIOD => I Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VITY-API (corr) Press. 24-HOUR ~TE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REC, Ei'VED SEP 2 3 2002 AnchOrage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Beluga 130 130 Tsuga 2-7A 658 658 Tsuga 2-7B 1272 1272 Tyonek/Carya 2-1 1753 1753 Casa 2-2 1923 1923 Carya 2-3 2210 2210 Carya 2-4C 2456 2456 Lone Creek 2720 2720 Carya 2-5 2840 2840 Carya 2-6 3257 3257 Carya 2-7 3798 3798 Carya 2-8 4330 4330 Carya 2-9E NP NP Carya 2-10 NP NP Juglans lb-1 GPC NP NP TD 5000 5000 RE., EiVEO SEP 2 3 2002 Al~~&Gae~s. Comm~ior Anchorage 31. LIST OF A-I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~..~L~.~.~,~.._ Title~ "~-~ ~'"(1~..~.~- Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, HydraulicPump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form10-407 Spud:9-12-00 RR: ( Lone Creek # 2 ( Rig: CC-1 Orl~l. Days: Ttl. Days: Anadarko Petroleum S: 30 I T: 12N I R: 11W TD: 5000 TD: Actual Wellbore Sketch GL: 394 I KIEl: 18.6 Driven ,/1 17 1/2" Hole 12 1/4" Hole 8 1/2" Hole Injected Reserve Pit @ 7" Shoe [~ 20". 92ppf. X-56 @ 92' 27 sx Abndmt plug 5'-170' 13 3/8", 68ppf, L-80 @ 244' 46 sx Abndmt plug 909'-1,100' 9 5/8", 40 & 47ppf, L-80 @ 998' Cmt Rtnr @ 1,906' 7", 26ppf, L-80 @ 2008' 182 sx Sqz below rtnr TD 5000' Summary of Drilling Operations Anadarko Lone Creek # 2, AOGCC 200-108, APl 50-283-20098-00 Anadarko Report Report Meas Mud Mud WOB Flow SPP No Date De )th Wt Vis mlbs gpm RPM psig Operational Summary 1 9/12/00 92 10.0 75 3 680 90 500 Spud 1600 hrs 9/12/00. Clean out conduCtor. - 2 9/13/00 245 10.0 85 3 680 80 400 Drill 12 1/4 hole to 245. Open to 17 1/2 to 227. 3 9/14/00 244 10.0 70 3 680 80 400 Finish opening hole to 244. Run and cmt 13 3/8 csg @ 244. 4 9/15/00 244 10.1 72 WOC. NU Diverter. 5 9/16/00 244 10.1 60 9 300 80 1525 NU and test diverter. MU 12.25 BHA and clean out shoe track. 6 9/17/00 508 10.2 4 4 372 78 850 DO to 270. TOOH for 8 1/2 bit and BHA. Ddll pilot hole to 508. 7 9/18/00 970 10.2 41 15 437 110 1350 Drill 8 1/2 hole to 970. TOOH. 8 9/19/00 1002 10.1 50 15 471 110 900 Open hole to 12 1/4 to 880. 9 9/20/00 1002 10.1 46 15 329 100 900 open hole to 12 1/4 to 998. Run logs. Run 9 5/8 csg. 10 9/21/00 1002 10.2 46 run and cmt 9 5/8 csg to 998'. ND diverter. 11 9/22/00 909 10.1 46 Finish ND diverter. NU BOPs. 12 9/23/00 909 10.0 46 NU and test BOPs. 13 9/24/00 1018 10 300 75 700 DO and perform shoe toest to 12ppg E. TOOH. 14 9/25/00 1085 10.5 52 10 257 100 625 Change over mud system to 10.5 PHPA sys. Drl to 1085. 15 9~26/00 1604 10.5 54 12 280 90 750 Drl 1085-1604. 16 9/27/00 1981 10.5 50 20 280 100 850 Drl 1604-1981. Worktight hole. 17 9/28/00 2163 10.5 48 20 315 100 1000 Continue to work tight hole. Drl 1981-2163. 18 9/29/00 2475 10.5 48 20 315 100 1100 Drl 2163-2475. 19 9/30/00 2899 10.5 48 25 317 100 1150 Drl 2475-2899. 20 10/1/00 3218 10.5 50 25 317 100 1150 Drl 2899-3218. 21 10/2/00 3575 10.5 52 25 317 100 1150 Drl 3218-3575. 22 10/3/00 4015 10.5 52 25 317 100 1350 Drl 3575-4015. 23 1014/00 4135 10.5 53 25 317 100 1350 Drl 4015-4135. Work tight hole and partial lost rtns. 24 10/5/00 4135 10.6 54 25 317 100 1350 Circ and cond. TOOH test BOPs. 25 10/6/00 4517 10.1 46 25 317 100 1350 Dr14135-4517. 26 10/7/00 4787 10.0 44 25 317 100 1350 Dr14517-4606. 27 10/8/00 5000 10.2 45 25 317 100 1250 Dr14606-5000. Circ and cond. - 28 1019/00 5000 10.2 42 TOOH. Run E-line logs (Aith/tldlcnllgrlmcfllcmrlsp) 29 10/10/00 5000 10.1 42 Logging (fms/rft). TIH with DP. 30 10/11/00 5000 9.5 52 Lay 73 sx balanced cmt plug 1950-2600. TOOH and LD BHA. TIH and drl firm cmt to 2018. 31 10/12/00 ! 1923 9.5 52 Run and cmt 7" csg @ 2008. 32 10/13/00 1923 9.5 52 ND/NU BOPS and test. 33 10/14/00 5000 9.6 45 DO and clean out to 2792. Perform PI test. 34 10/15/00 5000 Set cmt rtnr @ 1906. Test backside ok. Start injecting reserve pit. 35 10/16/00 5000 Continue injecting reserve pit. 36 10/17/00! 5000 Continue injecting reserve pit. 37 10/18/00 5000 Continue injecting reserve pit. 38 10/19/00 1906 Sqz 182 sx below rtnr in 2 stgs. 39 10/20/00 900 Spot 46 sx bal cmt plug 900-1100. Tag TOC @ 909. Spot 27 sx bal cmt plug 5-170. ND BOPs. 40 10/21/00 5 RD. CO wellhead and weld on DH marker. Rig released 1600 10/21/00. ANADARKO PETROLEUM CORPORATION 3201 "c" StrEeT, Suite 603 · TEL (907) 563-9519 ANCHORAGE, ALASKA 99503 TO' AOGCC 333 West 7th Avenue, Ste 100 Anchorage, AK 99501 RECORD'OF SHIPMENT FROM: Petroleum Corporation John Hartner Anadarko Petroleum Corporation 3201 C St. Ste. 603 Anchorage, Alaska 99503 ( ) Enclosed ( X ) Hand Delivered 113101 Subject: Lone Creek #2 ( ) Via Courier IQuantity Description Set of 16 boxes washed and dried samples (0'-5000') Epoch Mudlogging Report w/Formation Log (Mudlog) Sepia of Epoch Formation Log (Mudlog) Floppy disk of Epoch Mudlog digital data Floppy disk of Directional Survey & Wireline Run 1 data Floppy disk of Wireline Run 2(a) data Floppy disk of Wireline Run 2(b) data Floppy disk of Wireline Run 2(ab) data Print of Dipmeter Log (Run 1) Print of Array Induction Log (Run 1) Print of Compensated Neutron Lithodensity Log (Run 1) Print of Gamma Ray, Caliper Log (Run 2) Print of Array Induction Tool, GR Log (Run 2) Print of Repeat Formation Tester, GR Log (Run 2) Print of Density, Neutron, GR, Caliper Log (Run 2) Print of Combinable Magnetic Res. GR Log (Run 2) Print of Formation Micro Scanner, GR Dipmeter Mode Log (Run 2) Film of Dipmeter Log (Run 1) Film of Array Induction Log (Run 1) Film of Compensated Neutron Lithodensity Log (Run 1) Film of Gamma Ray, Caliper Log (Run 2) Film of Array Induction Tool, GR Log (Run 2) Film of Repeat Formation Tester, GR Log (Run2) Film of Density, Neutron, GR, Caliper Log (Run 2) Film of Combinable Magnetic Res. GR Log (Run 2) Film of Formation Micro Scanner, GR Dipmeter Mode Log (Run 2) NOTE: Please verify and acknowledqe receipt, by signing and returning a copy of this transmittal by mail, or fax to (907) 563-9479. Date: 1/3/01 Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi ~,c~,~ Petroleum Inspector DATE: October 21, 2000 SUBJECT: Plug & Abandonement #2 Anadarko Wildcat C oo_ NON- CONFIDENTIAL Section: 30 ToWnship: 12N Range: 11W Lease No.: CO61388 Drilling Rig: CC1 Rig Elevation: 18.5 Operator Rep.: Wile¥/Gosset Meridian: Seward Total Depth: 5000 ,CasinR/TubinR Data: Casinq Removal: Conductor: 20" O.D. Shoe@ 92' Casing Cut@ 5' Feet Surface: 13 3/8" .O.D. Shoe@ 244' Casing Cut@ 4' Feet Intermediate: 9 5/8 O.D. Shoe@ 998' Casing Cut@ 4' Feet Production: 7" O.D. Shoe@ 2008 Casing Cut@ 4' Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plu~inq Data: Bottom Top of Cement Mud Weight Pressure Tvl~e Plu~ Founded on ' (bottom up) of Cement Deoth Verified? above plu~l, Test Applied 7" surface Balanced . 165' 0 Visual 'N/A No 9 5/8" surface Balanced 25' 0 Visual N/A No 13 3/8" Surface . Bottom 244' 0 Visual N/A No Tvl3e Plu~ FOunded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface I arrived location and witnessed the pumpng of the surface plug in the 7" long casing string. 5.7 bbl's (27 sx) of G w/2% CaCI was circulated to surface from 165' below original grade through drillpipe. The 7"x9 5/8" anullus was pressure tested to 500 psi. The BOP's were nippled down and all casing strings were cut off to 4' below original grade. The 7"x9 5/8" had not been cemented to surface previously and the 9 5/8"xl3 3/8" cement top was down approx 5' below the casing stub. I required that all casings be cemented to surface and three jointsof 3/4" was rigged up. The two Annular spaces were blown dry and cement was mixed and Poured in from the top to fill the voids: A plate was welded inside the 13 3/8" casing to seal all inner annullus above the cement. The marker plate with the well information was welded to the top of the casing. cc.' T. Thompson (Anadarko drilling Supt.) Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Attachments: None Rev.:5/28/00 by L.R.G. VU35AEIG.xls 10/24/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment I Location Clearance I Suspended Well ( Title 20 AAC 25.170 ) FILE INFORMATION: Operator: Anadarko Petroleum Corporation Address: 17001 Northchase drive Houston~ Texas 77060 Surface Location (From Sec. Line): North/South 1956 FNL East/West 199 FWL Section: 30 Township: 12N Range: 11 Meridian: SM Well Name: ff.2 (Lone Creek) PTD No.: 200-108 APl No. 50- 283-20080-00 Unit or Lease Name: Lone Creek Field and Pool: Wildcat Downhole P&A Date: 10/20/20 20 AAC 26.120 - ABANDONMENT MARKER: Insp. Date: Surface Monument I Approval Date: Post OD: (4" m/n) ~" Length: ff. Set on __ (Wellhead, Csg, In Cmt) Height above f~nal grade (4' min.): ~ ft: Casing stub~ ff. below final grade Top of Marker Post Closed ?~ All openings closed ? __ Inspector: Insp. Date: 10/21/00 J Subsurface Monument J Approval Date: Marker Plate Diameter: 24 .... Distance below final grade Level: 4' Thickness: 1/4" Side Outlets removed or closed: Y Marker Plate Attached To Conductor N (Y/N) Cement to surface (all strings)? Y inspector: Leu Grimaldi Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date: 10/21/00 J J Approval Date: Anadarko Petroleum Corp Lone Creek #2 Permit #200-108 AP1#50-283-20098-00 Inspector: Leu Grimaldi Insp. Date: 'J 20 AAC 26.170 - LOCATION CLEANUP: I Approval Date: Pit's filled in? Liners Removed ar Buried? Debris Removed: Notes: Notes: Notes: Notes: General condition of pad/location: ( Rough, Smooth, Contoured, Flat, Natural ) Type of area surrounding location: Debris on surrounding area: ( Wooded,Tundra, Grass, Brush, Dirt, Gravel, Sand) Access road present? Type road: ( Dirt, Gravel, Ice, Other) Condition: ~ Condition of road: Cellar filled in? Type of fill: Height above grade: Type work needed at this location: Inspector: RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes Distribution: Reason: orig - Well file c - Operator Final Inspection performed? Yes ~ c - Database c - Inspector Final Approval By: Title: No ( If"No" See Reason ) No X DATE: Sheet by L.G. 8/5/00 Lone Creek surf abandon.xls 10/23/00 EG image 640x480 pixels Subject: Some stuff Date: Sun, 22 Oct 2000 22:14:04 -0800 From: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> Internal Organization: State of Alaska. Dept of Admin. AOGCC To: Blair Wondzell <blair_wondzell~admin.state.ak.us> ~i~P&A l~one Creek Type: Netscapc File (application/msexcci) i Encoding: base64 LG xls ~;" MTR GAS NorthStar fuel-gas 10-7-00 LG xls ' . '~'~ ' Type: Netscape File (applicat~on/msexcel) i Encoding: base64 ~i~MTR Gas North Star 10-7-00 LG.doc Name: MTR Gas North Star 10-7-00 LG.doc ~I Type: Microsoft Word Document (application/msword)} Encoding: base64 0/23/00 8:00 AN ~'EG image 640x480 pixels ~Lone Creek surf abandon.xls Lone Creek surf abandon.xls Name: Netscape File (application/msexcel)l Type: Encoding: base64 ~Pmdhoe tray 10-23-00 LG.xls] Type: Netscape File (application/msexcel) ]Encoding: base64 ~-~Ken trav 10-23 LG.xlsI Type: Setscape File (application/msexcel)! iEncoding' base64 ~ Louis Grimaldi <lou_grimaldi~admin.state.ak.us> 2 of 3 10/23/00 9:16 AI~ ANADARKO PETROLEUM CORPORATION 3201 "C" Street, Suite 603, Anchorage, Alaska 99503 Peter A. Leach-Consultant Off,-907 563-9478 Fax-907-563-9479 Mob.-303-908-9646 E mail--peter_lea ch ~anadarko. co m Petroleum Corporation Fax Transmittal TO: FROM' SUBJECT: CC' Blair Wondzell PHONE: FAX: Peter Leach PHONE: FAX: Lone Creek # 2-injection pressures October 16, 2000 Number of pages including cover sheet: 2 .................. IIlII ._ I II IIIIII I illi --, iiiiiii i i i i iiii MESSAGE: Blairmwe started injecting yesterday at 6 BPM (80 SPM) with i i75 psi pump pressure with the rig pump. After pumping 172 BBL of reserve pit water, the pressure increased and we had to switch over to BJ as the rig pump can only idle down to 40 spm. By midnight, we had pumped 1342 BBLs total and were pumping, at rates with pressures as shown in the table below. We apparently had picked up some obstruction in our string. When this happened, we started shutting down every 2 hours and taking an instantaneous shut in pressure as shown below in order to keep track of the pressure against the formation excluding friction pressures. These are all reasonable resulting in total pressure at the shoe of 1644 psi for the case of 775 psi shut in pressure. This compares to the apparent leak off pressure of 1440 psi surface on top of 9.4 ppg mud resulting in 2420 psi at the shoe. Thus, with 1644 psi at the shoe, we are well within the allowable pressure of 2420 -100= 2320 psi. (Note that the shut in pressures a few minutes after shutting down each time are identical to the instantaneous pressures indicating that we are injecting into a large reservoir). TIME RATE-BPM PUMPING PRESS-PSI INSTANT SHUTDOWN-PSI 1600 2.1 2300 705 1800 2.27 2200 706 2000 2.27 2185 710 2200 2.14 2316 775 2400 2.57 2411 706 THE INFORMATION CONTAINED IN THIS COMMUNICATION IS CONFIDENTIAL AND INTENDED ONLY FOR THE USE OF THE ADDRI=$$Ei=, ANY UNAUTHORIZED USE, DISCLOSURE OR COPYING IS STRICTLY PROHIBITED AND MAY BE ILLEGAL. IF YOU HAVE RECEIVED THIS COMMUNICATION tN ERROR OR IF IT IE, NOT LEGIBLE, PLEASE IMMEDIATELY NOTIFY ANADARKO AT THE ABOVE PHONE OR FAX NUMBER. 0600 3.42 1940 728 This morning, we have the pressures as shown above and have pumped a total of 2124 BBL fluid. Fluid density this morning is 8.4 ppg. I can be reached at office: 907-563-9478, Ce11-303-908-9646, home: 907-266-4210. Consultant THE INFORMATION CONTAINED IN THIS COMMUNICATION IS CONFIDENTIAL AND INTENDED ONLY FOR THE USE OF THE ADDRESSEE. ANY UNAUTHORIZED USE, DISCLOSURE OR COPYING I$ STRICTLY PROHIBITED AND MAY BE ILLEGAL. IF YOU HAVE RECEIVED THIS COMMUNICATION IN ERROR OR IF IT IS NOT LEGIBLE, PLEASE IMMEDIATELY NOTIFY ANADARKO AT THE ABOVE PHONE OR FAX NUMBER, L-one Creek # 2-- LOT Test Subject: Lone Creek # 2-- LOT Test Date: Mon, 16 Oct 2000 09:16:32 -0500 From: Peter Leach <peter_leach@anadarko. COM> To: "'Blair Wondzell'" <Blair_Wondzell~admin.state.ak.us> CC: Tommy Thompson <txtmid~DOMESTIC.EXCH.ANADARKO.com>, Joe Cox <jxc006~DOMESTIC.EXCH.ANADARKO.com> Attached please find the Fig 1 I should have sent yesterday instead of 2 Fig 2's. Sorry!! <<LC-2-LOT of Oct 14--7inch REDONE, 2000.xls>> ~LC-2-LOT of Oct 14--7inch REDONE, 2000.xls Name: LC-2-LOT of Oct 14--7inch REDONE, 2000.xls Type: Microsoft Excel Worksheet (applicatiOn/vnd.ms-excel) Encoding: x-uuencode 1 of 1 10/16/00 7:59 AM CASING TEST and FORMATION INTEGRITY TEST--ANADARKO PETROLEUM CORP--FIGURE 1 Well Name: Lone Creek # 2 Date: 10/14/00 Supervisor: Wiley/Gossett -- [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequancy for Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" 26 ppf (~ 2,008' Casing Setting Depth: 2,008' TMD Hole Depth: 2,023' TMD 2,008' TVD 2,023' TVD Mud Weight: 9.4 ppg Length of Open Hole: 15' EMW = Press 1,440 psi + Mud Weight -- + 9.4 ppg 0.052 xTVD 0.052 x 2,008' Pumped .75 BBL Bleed back .25 BBL EMW = 23.19 ppg Pump output = .0186 BPS 2,100 2,000 1,900 1,800 1,700 1,600 1,500 1,400 1,300 1,2O0 1,100 1,000 7O0 TIME LINE psi MINUTE TICKS / ,~, / I,I,I --e-- LEAK-OFF TEST --e--CASING TEST ...... ~'-"- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME ,TIMELINE psi psi psi psi psi J psi psi psi psi psi psi psi psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi Ostk 2$tk 4st~ 6stk 8stk 10 t2 14 t6 18 20 22 24 26 28 ~0 32 34 36 38 40 42 ~ 46 stk stk sUc ~tk st~ Stk stk ~tk stk stk st~ stk stk stk stJ( Stk stk Stk stk STROKES ~18 50 SU( Stk LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE 0 stks i 0 psi 2stks i 65 psi ..L. 4stks i 130 psi i .................... i. ............... ~ ................... j ........................ ~__s~_~.s____L .... _~__o_o._p_.s_! ..... 8stks j 345 psi ....................... ~_o_._s_t._~_s_._L .... _4_T~_P_.s_[ .... 12 stks J 620 psi L 14 stks ,,' 750 psi ........................ ~ ~. _s_L~_s_ _ _ L .... .~__o..o_p_.s_[ ..... 0 stks 0 psi ....................... .~_~_~.s_ ............ ~.o__.p._~L ....... 4 stks 150 psi L .................. ~.. ............... J ....................... J 6 stks 270 psi k .................. -*- ............... 4 ....................... ~ ....................... .~__sj~.s_ .......... ~.o._.p~! ....... 10 stks 500 psi 12 stks 575 psi ...................... .~__4_.s__~_s_ ......... ~_4__o__Rs_..i ....... 16 stks 860 psi k .................. -~- ............... ~ ....................... ~ 20 stks j 1,175 psi 20 stks 1,100 psi r ................... r ...............-t- ................... 1 r ............................................................ 22 stks i 1,230 psi 22 stks 1,240 psi 24 stks j 1,440 psi 24 stks 1,370 psi ~_ ................... i. ............... t'J- ...................J ~ .................. J- ...............J ....................... J 26 stks j 1,505 psi 26 stks 1,500 psi i .................... i. ............... i~- ................... ~ ~ .................. ~_ ............... ~ ....................... ~ 28stks j 1,595psi i- ................... ~- ............... .~- ................... ~ ~ .................. .~- ............... ~ ....................... ....................... ~_o_.?_L~_s___ ,,L__~_,~Z_o_..p_s_! .............................................................. 32stks ! 1,770psi 34stks j 1,850psi 1_ ................... L ............... .j_ ...................................... .J_ ....................................... 36stks i 1,920psi .................................... ,-l- .................... i ........................................ ........................ ._3_8___s_t.k__s___ L __~ :~ .7__o_ ._p_s_! ....... _s_._?.~_ :?_ ::~_~_ .......................................... 40 stks j 2,000 psi 0.0 min 1,500 psi ..................................... T .................... [ .... ?:6--r~i~- ........................................... .......................................... :_.,.4_.~__p_?j ..... .................................... i- ................... I 2.0 min 1,492 psi J ~ ~ ........................................................... SHUT IN TIME SHUT IN PRESSURE 3.0 min ~ .,. ~ 1,492 psi ~ i_ ................... i. ..................................... i ........................................................ , O.Omin ~ ~- 2,000 psi , 5.0 min 1,492 psi ..................................................... i~ .................. ~- ............... ~ ....................... ~ 1.0 min 1,580 psi 5.0 min 1 492 psi .................... i- ............... -i-- ................... ~ j- ..................-~- ................~ ....................... 2.0 min j ........................................................... 4.0 min 1,145 psi j .................... i. ............... J_ ................... 5.0 min j ~ ,_ 1,105 psi 6.0 min j ........................................ _~_,_o_z~__p_s_! .... L .... _7_.. _o_ _ .m_ ! _n_ ........................ _t,_o__4_~__p~!__. j8.0 min ~ + 1,030 psi I ,~ .................. ,'I' ............... 'J ........................ i- .................. -i- ....................................... .~ I' .................. -L. ...............J ....................... a NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY LEAK-OFF TEST 2,500 psi 2,000 psi UJ oc 1,500 psi Z ~- 1,000 psi 500 psi ~ I I i 0 psi -I 0~0 1.0 min i 2.0 min 3.0 min 4.0 min · 5.0 min 6.0 min 7.0 min 8.0 min SHUT IN TIME 9.0 min CASING TEST and FORMATION INTEGRITY TEST--ANADARKO PETROLEUM CORP .... FIGURE 2 Well Name: Lone Creek # 2 Date: 10/14/00 Supervisor: Wiley/Gossett [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight x Test after drilling out cement plug below 7" casing Casing Size and Description: 7" 26 ppf ~ 2,008' Casing Setting Depth: 2,008' TMD Hole Depth: 5,000' TMD 2,008' 'I'VD 5,000' TVD Mud Weight: 9.4 ppg Length of Open Hole: 2,992' EMW = Press 235 psi ~ Mud Weight = + 9.4 ppg 0.052 x-FVD 0.052 x 2,008' Pumped 20 BBL Bleed back 8 BBL EMW = 11.65 ppg Pump output = .0186 BPS 1,600 psi ; ', i I I -;L-- --~ ~ ---~ ...... .... __ /? I - -- ~ LEAK-OFF TEST ~ CASING TEST ---'~-- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME __ ~ TIME LINE / ......... ...... 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi i 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi ! OsU( 2stl( 4stk 65tk 85tk 10 12 lZ3 16 18 20 22 2z] 26 28 50 52 Sq 56 58 40 42 44 46 48 50 stk stk stk Stk 5tk 5tk st.k stk stk stk 5tk stk stk stk 5r.k stk stk Stk Stk Stk Stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOP, FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................... [ ............... T ................... i[ .................. T ............... l ........................ ..................... [---ii-;ii;;---T ..... -i)-¢;i .............................. i~--;i-i; ............ ii-i;;i' ........ .................... F ............... T .............................................................................. i 2stks i 38 psi 2stks 20 psi .................... i____4___s_t__k~___i ..... _S_3___p__s_! ............................. _4_.s__t_k__s_ .......... ].S__0_.p_s.j ....... "L 6stks .,- 62 psi , ~ ~- 6stks ~ 270 psi .................... l---ii-;ii~-; ........ ~,-i-¢;i .......................... ii-;i-~; ......... 3iii:,--i,;i ....... ................... ~ ............... .i= ................... 1 ~- .................. .i- ............... ~ ....................... 1 .................... L_?_._s_t__k_s_ ........ _8_o__.p_~! ........................... ]__O_~_t.k__s_ ......... _S__O_p_. _p_s__~ ...... i 12 stks 95 psi 12 stks 575 psi .................... L__j__4_. _s_t__k_s_ ....... .?_ _ _p_ .s_ [ ........................... J__4_~_t.k_~ ......... z~p_.p_s_! ....... .................... [__]_6_._s_t__k_s_ ....... .~__2_O_._p_s_[ ........................... ]__6_.s__t.k__s_ ......... _S_.6_p_. _p_s_! ....... i 18 stks 130 psi 18 stks 930 psi ................... ~- ............... .-~ ................... ~ i- .................. ~ ............... .~ ....................... ~ I 20 stks 145 psi 20 stks 1,100 psi ................... ~- ............... -~- ................... 1 r .................. 'T' ............... a ....................... i 22 stks 155 psi 22 stks 1,240 psi ..................... i__.2_~._s_Lk.s_ ....... _!9_o___e.s_[ ........................... .2__~_~_~ ........ ]_,__s~_o__p_?_[ ..... .................... i__.2_~._s_Lk.s_ ....... _?._p_.s_[ ....... - ................... .2__~_.s__~_s_ ........ .~_,_s.o__o__p_.s_~_ ..... ,: 28stks 183psi ................... ? ............... .~. ................... ~ ~ .................. .~_ ............... ~ ....................... ~ ................... j__.3__o_._s_t__k.s_ ....... .?_3_ _ _p_ .s_ [ ............................................................... i 32stks 191 psi { 34 stks ..... .2_ _0_0_ _ _p_ .s_ [ ................................................................ .................... L__.3_~._s_Lk.s_ ....... ~9_.~__P_~! ........................................... i 38 stks 217 psi SHUTINTIME ................... ~ ............... .~- ................... ~ ~ .................. .~- ............... .4 ....................... 4 i 40 stks 224 psi 0.0 min 1,500 psi ~ 42 stks 230 psi 1.0 min 1,492 psi i 44 stks 235 psi 2.0 min 1,492 psi I I I ........................................................... ~_ _ _ _s?_ _u_-[_ j _~_ _T_~ .~_ _ _ [ ................ _S_._ _U_'[_ _~ _~_ _~.~.S_ _S_U_ _~ 3.0 rain ......................................... j_;.4__9..2_p__sj_ ..... 0.0 min i 5.0 rain 1,492 psi .................... ~ ............... .-i- ...................~ ~. .................. -i- ...............4 ....................... .~ 1.0 min ! 5.0 min 1,492 psi 3.0 min z SEE .................... ~ ............... -F ............................................................................... 4,0 min i NOTE ................... i .................................. ~ 5.0 min i ' ..... ~-.-~--~;;- .... [ ............... T ................................................................................ .................... l- ............... ..-i- ................... i i- .................. -,,- ............... .i ........................ 8.0 min L IlL , ................... -I- ............... ~ ....................... ~ i ! ~ .................... ~ ............... ? ................... ; ............................................................ ' , ................... ,,' ............... ,,' ................... ~ ................... ; ............... j ....................... ~ NOTE: After 44 strokes, performed step rate test: 1 BPM (~ 290 psi, 2 BPM (~ 430 psi, 3 BPM (~ 550 psi, 4.5 BPM (~ 755 psi. Pumped 20 BBL mud total, bleed 8 BBL back NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY I_~ane Creek # 2--Leak offtests at 7" shoe Subject: Lone Creek/4 2--Leak off tests at 7" shoe Date: Sun, 15 Oct 2000 12:31:36 -0500 From: Peter Leach <peter_leach~anadarko. COM> To: "'Blair Wondzell'" <Blair_Wondzell~admin.state.ak.us> CC: Tommy Thompson <txtmid~DOMESTIC.EXCH.ANADARKO.com>, Joe Cox <jxc006~DOMESTIC.EXCH.ANADARKO.com> Blair-Per our recent conversations, attached please find the subject LOT tests. Figure 1 is the test after drilling out 15 ft below the 7" shoe and Figure 2 is after drilling through the cement plug into open hole (found bottom of cmt plug at 2200 ft and ran in hole to 2792 ft with no obstructions). As we discussed this morning, we are proceeding with injection starting later today once we get back in the hole with drill pipe and a cement retainer. Regards, Peter Leach <<LC-2-LOT of Oct 14--7inch REDONE after do cement.xls>> <<LC-2-LOT of Oct 14--7inch REDONE after do cement.xls>> 2o0 ,-- -- ~LC-2-LOT of Oct 14--7inch REDONE after do cement.xls Name: i.C-2-I .O'1' o'l': Oc1 14--7inch REDONE after do cement.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: x-uuencode Na~ne: LC-2-1..O'I' ol:(',')ct 14--7inch 'RI-~D()N 1.7 after do ' ..~ I.C-2-1,.(')'1' o1' ()ct 14--Tinch RED()NE after do ccment.xls c(:n'lent.xIs I ........................................ =: Type: Microsoft Excel %'orksh.ect I (application/vnd.ms-excel) Encoding: x-uuencode 1 of 1 10/16/00 8:00 AM he: Afiad~i'ko Petroleum Corporation Subject: Re: Anadarko Petroleum Corporation Date: Wed, 11 Oct 2000 08:16:54 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tommy Thompson <tommy_thompson~anadarko.COM> CC: 'Tom Maunder' <Tom_Maunder~admin.state.ak.us>, Dims 10 <dims 10~DOMESTIC.EXCH.ANADARKO.com>, Dan Seamount <Dan_Seamount~admin.state.ak.us> Tommy, Thanks for the program. Its as we discussed last evening. I do want to include some additional information. The TD is about 5000' In step d) of the Procedure, the EMW test should be to a surface pressure of 1050 psi. Also in step d) we need to analyze and approve the "FIT to break-over" prior to starting disposal. We will want to witness some of the abandonment operations, so please keep us appraised of your progress. We will most certainly witness the work proposed in steps h), i), and j). Good Luck with the program. Sincerely, Blair Wondzell, 10/11/00. Tommy Thompson wrote: Blair, Attached is a general procedure for disposal of drilling waste and plug&abandonment procedure for Lone Creek No. 2. As we discussed, Anadarko was unsuccessful in locating an open hole packer to perform the disposal of waste. This is our "fall back" procedure. I will be heading to Houston for a couple of days and Peter Leach will be supervising this operation in my absence. Peter can be reached at either 440-5700 (rigsite) or 563-9519 (Anchorage Office). If need be, I can be reached by mobile phone at 713-819-1796. <<LC2P&A. doc>> Name: LC2P&A. doc LC2P&A. doc Type: Microsoft ~ord Document (application/msword) Encoding: x-uuencode 1 ofl Anadarko Petroleum Corporation Lone Creek No. 2 Proposal to Dispose Drilling Waste and P&A 1. General Well Information: Lease: Well: API No.: Location: Moquawkie Prospect Lone Creek No. 2 50-283-20098-00 · 1,956' FNL & 199' FWL of Section 30, T12N, R11W 2. Casing Detail: Drive Pipe: Conductor: Surface: Injection: 20" ~ 92' (driven) 13-3/8", 68ppf, L-80, BTC ~ 244' Cmt'd. w/100sx Type 1 ~ 12.7ppg, tail w/100sx Type 1 ~ 15.Sppg. Circulated 37 Bbls. to surface. 9-5/8", 40 & 47ppf, L-80, BTC @ 998' Cmt'd. w/136sx @ 13.2ppg, tail w/296sx ~ 15.7ppg, Circulated 38 Bbls. to surface. 7", 26ppf, L-80, BTC to be run to +/- 2100' and cmt'd, w/13.2ppg lead (tie back to inside 9-5/8" csg. @ +/- 800') followed by 15.8ppg tail. 3. Procedure a) After completion of OH logging program, TIH w/open ended DP to +/- 2600', C&C and spot 30 Bbl. Viscous pill, b) Spot open hole cement plug (15.8 ppg) from 2,200' to 2,000',WOC, dress off to +/- 2,100', c) Run 7" csg., land ~ +/- 2,100' and cement w/13.2ppg lead followed by 15.Sppg tail (est. TOC at +/- 800' (tie back to 9-5/8" csg.), WOC, CBL is not required, d) Drill out float, cmt., shoe and 10'- 25' of cement plug, conduct EMW test to 0.5psi/ft, drill out remaining open hole plug to +/- 2,200', conduct FIT to break-over, notify AOGCC office of results prior to proceeding ahead, e) Run 7" cement retainer and inject drilling waste down 7" casing (record rate, pressure and volume), f) Follow drilling waste w/100sx 15.Sppg cement, sting out of retainer and check for flow, pressure test casing & dump 10sx on top of retainer, g) Spot 40sx cement plug (15.Sppg) at 1,100' to 900' (across 9-5/8" casing shoe depth), WOC, and. tag plug, h) Spot 25sx cement plug (15.Sppg) at 170' to surface, i) ND BOPE, cut off casing 3' below GL, weld on plate (mark according to regulations), no marker to be installed, j) RDMO rig & equipment, clean & remediate location as necessary. MEMORANDUM State [. ,~laska Alaska Oil and Gas Conservation Commission TO: Dan Seamount i~)(~-.j~ DATE: September 16, 2000 Commissioner SUBJECT: Diverter Functbn Test THRU: Blair Wondzell ~ Inlet Driling CC1 P.I. Supervisor ~ !~*;(¢O Anadarko ~ Lone Creek ~ FROM: Lou Grmaldi (.o~ ~ 200-108 Petroleum Inspector Cannery Loop Unit NON__.__- CONFIDENTIAL Operator Rep.' Bob Wiley Op. phone: Op. E-Mail: Contractor Rep.: Phil Fisher Rig phone: Rig E-Mail: MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: P Well Sign: P Systems Pressure: 3000 psig P Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Cbsure: 1750 psig P Reserve Pit: P Flare Pit: N/A 200 psi Recharge Time: :39 rain:sec P FullRechargeTime: 2:33 min:sec P Nitrogen Bottles: 4 @ 2500 PIF MUD SYSTEM INSPECTION: DIVERTER SYSTEM INSPECTION: Light Alarm Diverter Size: 13 5/8 in. Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Si'nuitaneous: P Flow Monitor: P P Vent Line(s) Size: 10 in. Vent Line(s) Length: 81 ft. GAS DETECTORS: Line(s) Bifurcated: N/A Light Alarm Line(s) Down Wind: P Methane P F Line(s) Anchored: P H2S: P P Turns Targeted / Long Radius: N/A Test's Details I arrived to fhd the rig still assembling the vent line. They had attempted to add a third section of vent line earlier this morning but could not access marsh alongside the rig without g~ing equipment stuck. After measuring what line they had I determined they were within compliance for b'ngth and just needed to get past a small Conex. This was accomplished by adding another ten foot section. The line was secured to pallets of "Gal" The functbn test went well with the vent line valve opening promptly and the 13 5/8" annular preventer closing within 1 minute. The gas detectors were tested with all operating exc__e~t for thesensors at the bell nip~. This will be repaired before the rig drills out. The rig appeared to be in good shape and is ready to dril surface hole on this well. The location was clean and well laid out. This is the second Anadarko I have been on and as was the first location this one was well arranged with attention paid to secondary containment. Total Test Time: 3 Number of failures: 1_ Attatchments: None, cc: Peter L~ch/Tomm¥ Thompson '----- Diverter CC1 9-16'00 LG.xls 07/11/00 TUE 13:05 FAX 907 694 1807 003 STORM WATER POLLUTION PREVENTION PLAN LONE CREEK WELL NO. ,2 ACCESS ROAD SITE DESCRIPTION Project Name Lone Creek Well No. 2 Access Road- Moquawkie Prospect Location West Side of Upper Cook Inlet, Kenai Peninsula Borough. The wellbore will be situated at latitude N61.103741, longitude W-151.308059, with the access road extending from the existing Tyonek Road System to the Lone Creek Well No. 2 well site. (See Exhibit A) Facility Operator Anadarko Petroleum Corporation P.O. Box 1330 Houston, TX 77251-1330 Property Owner Tyonek Native Corporation 1689 "C" Street, Suite 219 Anchorage, AK 99501 907/272-0707 Project Description The project is located on Tyonek Native Corporation surface some 6 miles WNW from the village of Tyonek, Alaska. Leased acreage encompasses approximately 6,500 acres, Development will consist of site grading and leveling as necessary to upgrade 1 - 2 miles of existing road. New construction of approximately 1.6 miles of gravel road will be required. Clearing and grubbing, removal of overburden, grading, placement of gravel, and compaction in place will be required during the Construction process. The road and pad will be designed to provide all weather access. Total acreage impacted by new road construction is four (4) acres (22' base x 1.6-mile length). The well location pad is proposed to be constructed in similar fashion to the roadway. The subject pad will be E I-- 1' I -.: :...-';?.,'.-."':~..:!:,-c' "~ :-.~.:'-'.-.~.:".:- 7."(..-',, '..:'-."-F,::.. :~' .. :: '-: -'"~ ::.-'¢ ::-"' ...... -:,'-1-'~ I-'- :' :'-'-' -" --17:~ ~," ... · ... -.. ,':~ .~ ~ ,,' ~ .:,. · · . ~ -~',,..'~,,:,.' ~..:· . - - :,---~.,... ::,,vi- .~...,' ,- ~... ,-,.~m':.-'.,.".~ ' -':.'-' :" "'~ .. .... : :..,.¢~.-..:.~_.:_'::,._?-.::.::;...-:.: .'.: '..'-i!:.--.. .... "-".;'.-.'~-,':~ ;:. · .'.:"-?~;'v,..--"-.?-::-.,:.'.'-: '..: ,' :'...~i'- '"'- ..~ .'.;! · .' .! ;.-'. ,f..: ...-1 .'. ,~ .... ,. - -4;.:' - ' " ': !:,~,..::..- ..;; · -_,::~.: ..' ~.. ,:~ ~.-:.'.:' ?...;. '...?:..::: ~..... .. ?. ?.'.~.'.:. .... '~ :'.....--,?:.., .~..: ~.', -... ~ .-.': . ';."%- "' :'-:-;: ."'~'~ :"~"..:-- .: "':-. '."i'.;','"' ]:.; ', V . .-;..[-:~,?i..'..;,...:-..-~.--. ~:: . ..,,::'".: ...,:.-.'. . '. I-. "( .'~-.' "-..', ~-C'"': :'-:~,~'~ : .; '~ ,', :. ~:-i : ';' '::?-:...: :~"~":': :',:;,:'~::. ':.-i' M~p -19~.,.7 -' I'" .- ' ["' ' "~ "~' ''~' """ ;.:-: ~,:',. '- ...~ ..-',.: ':.:~-.::.'..~ ~. .... · ';".. ';' ":' "-...':/'./"i. , !'"., _-. -:', ...:: .'-&::.... ~: · .~ .:'..~ ~' ..... . I ~'~" .;.: .",' ,, -.?:'.:. Lbne Creek Well No. 3 .:-~,.$:. . "" I · . .-'-.' - 4 I I '.., ...... I ,. t~ ,. · '..' ,~,~; - ,. ..... . . . -:.-..:::-<'.--..--- : ''._.,'..: ....... .,-:-J,..-- -:.L.'__~'-'.~:.".I,"-~.-:-,:'-':- , ':' - --1:i':'." ' ; ',: '-'"-":=~-'-:--'"'"':": '- ~: ..... :..,'": : · :';~.,-'J"'-.",:'.': ; ' ' :::' .... - "-t- .=.';:"-:--:~" :" .-'.'. -.c,'~' :.,--'.-;-,:-;. , :,~....,'-:-. ~ . ~:~-~ ~...-~-'.-.-.:,.-.~?:+..?? :.'.'.: ..... .-::.:.,'-:,~....-:.::,.,-,:..,- !..-'..:-.'..:,:;';-:........-. :: ·: : .- -. :- .u.-. .... - ..... ....,., ..---: . ...: :.:..'.- .'- , , '-:~.. ¢--.: j, ,,.; .:., . · ~..'.-,.~-,'.--.'_..¢ ~,:._C:~:::-:;.:-.--.:.'.~': 3'. '..',-_ .:-' .-:--:- ,' "-." .~: .'." :,'v,-:.' .'."'.' -'..:. :' .:-'". ,, .. · .. . . ·. . . '. : .. · . '- : .. . · - . ¢ -- . -.%.:,,~g~-~ :, r- - .~ ---. -.~.'...' · .... -,-;---.. .- , .- .' · ..: .. · · . - .-.- ... '- .. . · , '. . .' .. ' 3'..-' -' . ...... . ' ".;-: '-' ' '"" '~':" "" ': ..... """ .~ :'; "'-:/-' ' ' ·: °' ' ~4'~.a~..:- :'-;'" -' .'- C-,:.' ·. -: ~ '--- ': -- :": ;' -- .- .7 .. -.-.. - . .- - -:', · - ..:.. :' -:..... '.... '.. '-::. :.., __ ii ii!1 ! i i i 09111/00 Lou, a note to confirm our conversation of intentions to spud this evening. Will call with an up date tomorrow as planed. Bob Wiley CC: Tommy Thompson I'd ~9L-89~ LO6 A3~IM AffD8 d~:~O OD It dos ALASKA OIL AND GAS CONSERVATION COPlMISSION Tommy Thompson Division Drilling Superintendent Anadarko Petroleum Corporation 17001 Northchase Drive Houston, TX 77060 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Lone Creek #2 Anadarko Petroleum Corporation Permit No: 200-108 Sur. Loc. 1956'FNL, 199'FWL, Sec. 30, T12N, R11W, SM Btmhole Loc. 1956'FNL, 199'FWL, Sec. 30, T12N, RI 1W, SM Dear Mr. Thompson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Anadarko's request for a variance from the diverter vent line requirements is denied. 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. _'~cere. ly,. Commissioner BY ORDER OF THE COMMISSION DATED this / 3'7'" day of September, 2000 rill/Enclosures cc: Department of Fish & Game, Habitat Se'chon w/o encl. Deparm~ent of Enviromnental Conservation w/o encl. August 25, 2000 Cammy: Lone Creek #2 well lies 200 feet from the western border of CIRI's lease C-061388. It is within 200 feet of the boundary between C-061388 and CIRI's lease C-061389, which lies to the west. In their cover letter for the Permit to Drill Application, they requested a spacing exception based on being within 500 feet of a quarter section line if oil is discovered or within 1,500 feet of a quarter section line if gas is discovered. Our land 1997 vimage land status map for the Cook Inlet indicated ARCO is the operator of these two leases. My concerns were: · is there a change of ownership across the lease boundary (which would require a spacing exception), and · who current operates these leases. I phoned CIRI to obtain current land status map. Tyonek village owns surface rights to both leases, and CIRI owns the subsurface rights (see attached map, pertinent leases are located in left center). According to the current 20 AAC 25.055, a spacing exception is not required. I also requested, and received, a change of operatorship designation from Anadarko. I looked over the operatorship designation, and it appeared fine. I passed it to Bob for his review. He phoned Anadarko and requested the change of ownership designation, which we received. Please let me know if you need additional information. Steve Davies T~3N R12WL~ C~06:~50~ C-061500 RI0W 1N R'i0W T¥onek ~ Oil & Gas Leases '~.'~ Phillir}'s Alaska, ~nc: 50% 0'~ Anadarko Petroleum Corn 50°,4 Oil & Gas Umts Vdtage Subsurface Village Surface CIRI Subsurface ~¢>.sjCIRt Surface CIRI Subsurface ~CiRI Surface & Subsudace Cook k~let Region nc. 0 I 2 3 ,~ Miles ~oouawk~e oil & Gas Lease To: Blair Wondzell August 21, 2000 Fr: Tom Maunder ~--~~~~ Re: Lone Creek #2 (200-108) Request for Diverter Exception Operator's Request and Justification Anadarko Petroleum plans to drill the Lone Creek #2 exploration well as a follow-up to their previously drilled Lone Creek #1 (198-084). In their application, Anadarko has requested an exception to the diverter line size requirement at 20 AAC 25.035 (c) (1) (A) and the hole size requirement at 20 AAC 25.035 (c) (1) (B). 20 AAC 25.035 (c) (1) (A) requires that the diverter line be at least 16" diameter, unless a smaller size is approved by the commission to account for ... rig layout... 20 AAC 25.035 (c) (1) (B) requires that the diverter line diameter be at least equal to the planned hole diameter unless a pilot hole is drilled first. The commission may waive this requirement if the operator demonstrates, based on drilling experience in the near vicinity, that drilling a pilot hole would not be necessary for safety. In support of their request, Anadarko has submitted 1--A shallow hazards evaluation as an attachment to the 401 application. No seismic anomalies indicating the presence of gas have been identified. 2--A 13-3/8" structural casing will have already been set at 200' to isolate the quaternary gravels at the surface. 3--Conducted a review of the drilling records for the 10 existing wells within a 3- mile radius. Shallow gas was not noted in 9 of the wells. The lone exception was the Mobil Moquawkie #1 drilled in 1965. This well experienced a blowout in an interval correlated to an equivalent depth that is approximately 200' below the intended casing point. The blowout is believed caused by swabbing. Anadarko believes that their drilling and tripping practices are significantly better than those employed 35 years ago and cite their experience with the Lone Creek #1. Information Review I have reviewed the file from the Lone Creek #1, which spudded in June 1998. The #1 location is about 8000' NE of the proposed #2 location. On the Lone Creek #1, Anadarko drilled a 12-1/4" hole from 255' to 950' employing a 10" diverter line. The 12-1/4" hole was drilled as a pilot and eventually was opened to 17- 1/2". The diverter line size employed was in accord with the then current regulations. The 16" diameter proscription and the consideration of hole versus diverter line size were enacted when the new regulations were made effective in November 1999. The drilling records indicate that Anadarko did experience swabbing and improper hole fill while attempting to trip after reaching 950' in 12-1/4" hole. After circulating and conditioning, they pumped out of hole, logged and then began opening the hole. No gas problems are indicated opening to TD and then tripping. When they returned to bottom, the report indicates that they experienced 2 gas bubbles over the rotary table and reported gas units at 3500. They then raised the mud weight to 9.8 and pumped out of hole to LD the opener. They ran back in and circulated and conditioned and again pumped out to run casing. No gas problems were reported on the final trip out. The casing was run without incident and cemented to surface. After ND the diverter, gas was discovered working out of the cement in the 13-3/8" annulus. The diverter was reinstalled and 100-psi positive pressure was put on the annulus and monitored with no decline reported. Further monitoring indicated that 10-psi would build up under the closed diverter. 3.5 days after bumping the plug the starting head was finally installed. Discussion The plan for Lone Creek #2 is in many ways similar to the Lone Creek #1. Ultimate hole sizes have been reduced, however the proposed 12-1/4" hole section is essentially the same as drilled in 1998. It is evident from the drilling record that there is gas in the intervals above 1000'. With the shallow depth of the interval, it is difficult to provide much overbalance without significantly raising the mud weight and risking lost circulation. The problems encountered with gas after nippling down further confirm gas in the interval and that reducing the hydrostatic pressure does allow gas to enter the well bore and percolate to surface. I have talked with Peter Leach of Anadarko regarding the actions last year. He indicated that raising the mud weight to 9.8 did suppress the gas readings and that pumping out on the trips after that was a precaution to avoid any possibility of swabbing. With regards to the gas after cementing, Peter indicated that they plan to reciprocate the pipe and get the slips set as soon as possible to seal the annulus. Anadarko feels that with last year's experience and the same personnel on site (Bob Wiley) this year that they are prepared to safely drill the surface hole. Decision In their presented plan for Lone Creek #2 and in discussions with the personnel in responsible charge, they are well aware of the potential drilling hazards of the surface hole. They have advanced a drilling plan employing mud weights (9.8 - 10.0 ppg) and tripping practices (pumping out) whose goal is to prevent swabbing. They have also made changes to their cementing program to possibly incorporate gas-blocking additives (if temperatures don't preclude their use) and getting the slips set as soon as safely possible. In a surface hole, regardless of hole diameter, well control is dependent on the drilling and tripping practices employed. The diverter, regardless of size, is there to direct an uncontrolled flow away from the rig floor to allow personnel to safely escape. Based on the information presented on offset wells, the experience at Lone Creek #1, their personnel continuity and proposed plans for drilling the surface hole at Lone Creek #2, I recommend that Anadarko's requests for exception be granted. Anadarko Petroleum Page I of 17 Operations Summary Report D£-*C *[998 ' ......... Legal Well Name: Lone Creek #1 ST-1 ~ ..... ~ Common Well Name: Lone Creek #1 ST-1 Spud'D~ite: 6/27/98 ' ' ' Event Name: ORIG DRILLING Start: 6/22/98 End: Contractor Name: Nabors #160 Rig Release: Group: Rig Name: Nabors #160 Rig Number: Sub Date From-To Hours Code Code Phase Description of Operations 6/22/98 00:00 - 00:00 24.00 1 1D MIRU Rig Up / Rig Down / PreParation 6/23/98 00:00 - 00:00 24.00 1 1D MIRU Rig Up / Rig Down / Preparation 6/24/98 00:00 - 00:00 24.00 1 1D MIRU Rig Up / Rig Down / Preparation 6/25/98 00:00 - 00:00 24.00 1 1N MIRU Continue to dg up, make ready to spud. 6/26/98 00:00 - 00:00 24.00 I 1D MIRU Rig Up / Rig Down / Preparation 6/27/98 00:00 - 03:30 3.50 23 23J MIRU P/U 17 1/2.' bit, 8" OD DCS' 03:30 - 15:30 12.00 2 ?_.A DRLCON Spud well ~ 0330 hrs 6~27~98, drill 17 1/2. hole t/260' 15:30 - 16:00 0.50 5 5B DRLCON C & C 16:00 - 18:00 2.00 6 6A DRLCON TOOH, P/U 26" hole opener 18:00 - 18:30 0.50 7 7A DRLCON Lubricate Rig 18:30 - 19:00 0.50 23 23J DRLCON Finish makeing up BHA 19:00 - 00:00 5.00 23 23J DRLCON Open 17 I/Z' hole to 26" 6/26/98 00:00-04:30 4.50 3 3C CSGCON Open 17 I/Z' hole to 26" to 258' 04:30 - 05:00 0.50 5 5A CSGCON Circulate and Condition Mud 05:00 - 05:30 0.50 6 6D i CSGCON POH 05:30 - 06:30 1.00 6 6C ~CSGCON Clean BHA. RIH 06:30 - 08:00 1.50 5 SA I CSGCON Circulated and Conditioned Mud I 08:00 - 10:00 2.00 6 6B CSGCON i POH. Laid down bit and hole opener. 10:00 - 14:00 4.00 12 12B CSGCON Rig up casing equipment' 14:00-18:00 4.00 12 12C CSGCON Run 6 joints 20" g1.51# X56 .375wt buttress casing to 255'. 18:00 - 19:30 1.50 5 5M CSGCON Install swedge. C&C. L/D casing tools 19:30 - 22:00 2.50 12 12S CSGCON Rig up false rotary. Make up cementing stinger. RIH on HWDP. 22:00 - 23:00 1.00 5 5A CSGCON Establish circulation at 10 bpm/500 psi. Circulate and condition mud 23:00 - 23:30 0.501 23 23B CSGCON Hold Safety Meeting 23:30-00:00 0.50 12 12N CSGCON Pumped 5 bbls fresh water. Tested lines to 200O psi. 6/29/98 00:00 - 00:30 0.50 23 '23J CSGCON Using Dowell cmt 20' csg wi 310 sks class "G" cmt mixed w, 4.6% CACI.2, & 4% Bentonite, mixed ~ 12.Sppg, slurry vol. 113bbls, followed by 259 sks class "G" cmt mixed w/2% cacl2, slurry vol. 54 bbls, cmt to surface wi 92 bbls pumped, wi full returns throughout job 00:30 - 01:30 1:00 6 61 CSGCON TOOH wi HWDP 01:30 - 05:00 3.50 23 23J CSGCON nipple down 30" 05:00 - 10:00 5.00 14 14A CSGCON Cut 20" csg weld on 20" starter head 10:00-20:30 10.50 14 14B CSGCON N/U20"divertersystem 20:30 - 00:00 3.50 23 23J CSGCON Attempt to fuction test diverter valves wi valve at well head being very slow to open, repair valve. 6/30198 00:00 - 04:00 4.00 15 15D CSGIN1 Work on diverter valve & koomey lines. Finish funCtion test. 04:00 - 06:00 2.00 15 15D CSGIN1 Rig up v-door slide. 06:00 - 07:30 1.50 23 23J CSGIN1 L/D stabing board, change elevator bails. 07:30 - 08:00 0.50 7 7A CSGIN1 Lubricate Rig 08:00 - 08:30 0.50 6 6A !CSGIN1 P/U 17 1/2'' bit, TIH to 247' 08:30 - 09:00 0.50 2 2G CSGIN1 Ddll firm cmt. f/247' tr252' 09:00 - 09:30 0.50 2 2H CSGIN1 DHII out of shoe {~ 255' 09:30-11:00 1.50 2 21 CSGIN1 ' Dfill from 255' to 270' (15') 111:00- 12:00 1.00 6 6A CSGIN1 :TOOH 12:00 - 17:00 5.00 23 23J CSGIN1 P/U surface hole BHA, TIH 17:00 - 23:00 6.00 2 2A CSGIN1 Ddll f/270' t/500' 23:00 - 23:30 0.50 5 5A CSGIN1 I Circulate for survey 23:30 - 00:00 0.50 10 10B CSGIN1 i Survey (~ 485'- 1t2 degree 711198 00:00 - 09:30 9.50 2 2A DRLIN1 Ddll 12.25 hole f/500' t/950' 09:30 - 12:00 2.50 5 5B DRLIN1 CBU Pdor to Tdpping 12:00 - 12:30 0.50 10 10B DRLIN1 Survey ~} 916' - 3/4 degrees 12:30- 13:30 1.00 5 5B . DRLIN1 CBU Pdor to Tripping Print~l: 10/13/98 1:39:2~PM ,~~1~ Anadarko Petroleum Page 2 of 17 Operations Summary Report Legal Well Name: Lone Creek #1 ST-1 Common Well Name: Lone Creek #1 ST-1 Spud Date: 6/27/98 I Event Name: ORIG DRILLING Start: 6/22/98 End: Contractor Name: Nabors #160 Rig Release: Group: Rig Name: Nabors #160 Rig Number: Sub Phase Description of Operations Date From-To Hours Code Code , . 7/1/98 13:30- 14:30 1.00 6 6C DRLIN1 Wiper Tdp, pull 4stds w/ hole swabing, TIH, C&C BU W/maxof 2600 units of gas w/gas units falling to 90 !14:30- 16:00 1.50 5 5B DRLIN1 CBU Priorto Tdpping 16:00 - 18:00 2.0016 ~6W DRLIN1 POOH to Log 18:00- 18:30 0.50123 :23B DRLIN1 Hold Safety Meeting 18:30 - 19:00 0.50 7 !7A DRLIN1 Lubricate Rig 19:00 - 20:30 1.50 6 6C DRLIN1 Wiper Tdp 20:30 - 00:00 3.50 6 6D DRLIN1 Check Tdp,-hole not taking proper amount of fluid,start TIH 7/2/98 00:00 - 00:30 0.50 6 6D DRLIN1 TIH to Btm. (~ 950' C&C mud, monitor well 00:30 - 02:30 2.00 6 6C DRLIN1 TOOH Pumping out 02:30 - 06:30 4.00 11 11J DRLIN1 Open Hole Logging wi Schlumberger from 950' to Btm. of 20" csg. ~ 255' 06:30 - 07:00 0.50 7 7A DRLIN1 Lubricate Rig 07:00-11:30 4.50 6 6A DRLIN1 PIU1711'Z' Hole Opener, Chg. stab. sleeves from12114' to171/2" 11:30 - 12:00 0.50 3 3C DRLIN1 Open hole from 270' tO 310' 12:00 - 14:00 2.00 8 8A DRLIN1 Repair finger in derrick, repair Iow drum clutch, Rig evacuation drill 14:00 - 15:30 1.50 2 2A ! DRLIN1 Open hole from 12 1/4' TO 17 1/2" TO 341' 15:30 - 16:30 1.00 8 8A DRLIN1 Repair Low Drum clutch. 16:30-00:00 7.50 3 3C DRLIN1 i Open hole from 12 1/4" to 17 1/2" from 341" to 832" 7/3/98 00:00-02:30 2.50 3 3C DRLIN1 ! Open hole f/12 1/4" to 17 1/2" f/832' to 950' !02:30- 04:00 1.50 2 2A DRLIN1 Drlg w/12 1/4" bit and 17 1/'Z' hole opener f/950' to 968' 04:00 - 04:30 0.50 5 ~5B DRLIN1 Circ for wireline survey 04:30 - 05:00 0.50 10 108 DRLIN1 Run s/s on wiretine {~ 948' 1/2 degree N56w 05:00 - 06:00 1.00 5 5B DRLIN1 CBU Pdor to Tdpping 06:00 - 06:30 0.50 5 5C ;)RLIN1 Cim, (10 min. flow check) 06:30 - 07:30 1.00 6 6C DRLIN1 Wiper Tdp 07:30 - 09:30 ZOO 6 6C DRLIN1 TOOH, clean BHA, TIH 2 gas bubbles over Rotaey Table 09:30 - 10:00 0.50 6 6C DRLIN1 TIH 10:00 - 15:00 5.00 5 5A DRLIN1 CBU, 3500 units of gas, measure Mud Wt. Temp. and gas units. Raise Mud Wt. to 9.8 ppg. 15:00 - 16:30 1.50 6 6C DRLIN1 TOoH pump out to BHA 16:30 - 21:30 5.00 6 6A DRLIN1 Stand back BHA, TIH picking up 5" dp breaking circulation & checking for flow (~' 380', 763' & TD ~ 970' 21:30 - 00:00 2.50 5 5F DRLIN1 C & C, dg up casing stabing board 7/4/98 00:00 - 02:00 2.00 6 6D I CSGSUR Check flow, use top drive pumping OOH 02:00-04:00 2.00 12 12B !CSGSUR Start rigging up to run13 3/8" casing 04:00 - 07:00 3.00 6 6D CSGSUR 'M/U bit, TIH 07:00 - 07:30 0.50 5 5A CSGSUR IW/bottoms up check flow 07:30 - 08:30 1.00 6 6D CSGSUR I Use top drive pump out of hole 08:30 - 09:00 0.50 6 6A CSGSUR L/D BHA 09:00 - 10:30 1.50 12 12B CSGSUR Rig up casing tools 10:30-16:00 5.50 12 12U CSGSUR SafetY meeting, run13 3/8' CSG. i 16:00 - 16:30 0.50 5 5M CSGSUR Circ hole volume 16:30 17:00 0.50 12 12B CSGSUR Rig down csg tools 117:00-22:00 5.00 12 12M CSGSUR TIH w/ stab in tooI,Rig up side entry sub !22:00-23:30 1.50 5 5M CSGSUR Circ. prior to cemenflng, 3Omin. safety meeting while ¢irc. 123:30 - 00:00 0.50 12 120 CSGSUR Mix and Pump Cement 715/98 !00:00 - 01:30 1.50 12 120 DRLSUR Using Dowell mix & pump 493 sks class "G" cement, slurp/volume 180bbls followed by 385sks class "G" cement mixed (~ 15.8ppg with plug down {~ 0130 hrs 7/5/98, release pressure, floats held Printed: 10/13/98 1:39:25PM ~A.==L-~l~ Anadarko Petroleum Page 3 of 17 Operations Summar Report Legal Well Name: Lone Creek #1 ST-1 Common Well Name: Lone Creek #1 ST-1 Spud Date: 6/27/98 Event Name: ORIG DRILLING Start: 6/22/98 End: Contractor Name: Nabors #160 Rig Release: Group: Rig Name: Nabors #160 Rig Number: Sub Date From - To Hours Code Code Phase Description of Operations 7/5/98 01:30 - 02:30 1.00 6 61 DRLSUR Remove cmt head, sting out of float collar, pull two stds, displace DP 02:30 - 04:30 2.00 6 6V DRLSUR TOOH 04:30 - 06:00 1.50 23 23J DRLSUR Pump through & drain BOP flowline 06:00 - 10:00 4.00 14 14A DR LSU R Nipple down diveter system. Make rough cut on 13 3/8" casing. 10:00-10:30 0.50 13 13A DRLSUR Rig down stabbing board, found gas worldng out thmugh cmt in 133/8" annulus. 10:30-18:30 8.00 14 14A DRLSUR Nippleup divertersystem, place jt of13 3/8" in hyddl & pressure to100psi, monitor pressure wi no pressure increse 18:30 - 20:00 1.50 23 23J DRLSUR Bleed pressure off, rig up bleed off line to reserve pit. sA well, monitor well, no pressure 20:00 - 00:00 4.00 23 23,1 DRLSUR Monitor pressure on annulus 7/6/98 00:00 - 09:30 9.50 23 23J CSGSUR MOnitor annulus for surface gas. 10 psi 09:30 - 10:00 0.50 14 14A CSGSUR NipPle Up/Nipple Down BOP 10:00- 13:30 3.50 23 23J CSGSUR Other 13:30 - 14:30 1.00 14 14A CSGSUR = Nipple Up/Nipple Down BOP 14:30 - 18:00 3.50 23 23J CSGSUR Monitor wall, hold 50 psi on csg. 18:00 - 18:30 0.50 23 23J CSGSUR Bleed pressure off annulus. 18:30 - 19:00 0.50 23 23J CSGSUR Check for flow 19:00-00:00 5.00 23 23J CSGSUR Monitor annulus, holding 50 psi back pressure. Rigging up gas buster. - CSGSUR 7/7/98 00:00 - 00:30 0.50 23 23J CSGSUR Monitor wall (~ 45 psi. 00:30 - 01:00 0.50 23 23J CSGSUR Bleed off wall. Check flow 01:00-17:00 16.00 23 23J CSGSUR Raise pressure on annulus to 50 psi. Monitor well. 17:00-18:00 1.00 14 14A CSGSUR RemoveHydril, dress13 3/8' csg. & 20" ffange. Set packoff & 20" flange. Apply 50 psi water pressure and sniff for gas. 150 units of gas. 18:00-19:00 1.00 23 23J CSGSUR Monitor annulus {~ 50 psi 19:00 - 22:00 3.00 14 14A CSGSUR Remove V-door and catwalk, nipple down diverter spool and Hydril 22:00-00:00 2.00 14 14A CSGSUR Make final cut on 133/8"csg. PJSM, weld on wetl head. 7/8/98 00:00-12:00 12.00 14 14B DRLIN1 Finish cut 13 3/8 csg, wald on 13 5/8 starting flange and allow to cool 12:00 - 00:00 12.00 14 14A DRLIN1 Nipple up 13 5/8 BOP Stack, Rig up poor boy degasser and vent line 7/9/98 00:00-06:00 6.00 14 14B : DRLIN1 Rig up BOPand Degasser vent lines 06:00- 14:30 8.50 15 15A DRLIN1 Test BOP,s 14:30 - 00:00 9.50 6 6A DRLIN1 Lay down 17 1/2 BHA, make up 12 1/4 BHA, P/U 5" HWDP 7/10/98 00:00 - 04:30 4.50 2 2G DRLIN1 : RIH picking up HWDP to FC ~} 923' 04:30 - 06:30 2.00 2 2G DRLIN1 Pump through choke, gas buster, C & C to top of float collar ~ 923' 06:30 - 14:00 7.50 5 5A DRLIN1 !C & C mud 14:00-16:30 2.50 2 2G DRLIN1 Using Dowell test 13 3/8" csg to 2000psi 16:30 - 17:30 1.00 2 2G DR LIN1 Drlg FC & 20' in cmt jt t/944' 17:30 - 18:00 0.50 23 23J DRLIN1 Circulate B/U test casing t/2OOOpsi 18:00 - 20:30 2.50 2 2H DRLIN1 Drill Shoe Track 20:30 - 21:30 1.00 2 2A DRLIN1 Vertical Rotary '21:30 - 22:30 1.00 5 ~5A D RLIN 1 Mud Conditioning / Cooling / Heating !22:30-00:00 1.501 11 Illl DRLIN1 Perform Leak Off/F.I.T. 7/11/98 00:00-15:30 15.50 2 ?_.A DRLIN1 Drill f/978' t/1244' 15:30 - 16:00 0.50 5 5C DRLIN1 C & C, check flow 16:00 - 16:30 0.501 10 lOB DRLIN1 SS survey (~ 1244'-3/4 degree 16:30 - 00:00 7.50, 2 2A DRLIN1 Drill f/1244' t/1375' 7/12/98 00:00 - 15:30 15.50 2 2A DRLIN1 Drill f/1375' t/1650' 15:30 - 16:00 0.50 5 5A DRLIN1 Circulate bottoms up, check flow 16:00 - 17:00 1.00 6 6D DRLIN1 5 std short trip 17:00 - 17:30 0.50 5 5A DRLIN1 Circulate bottoms up 17:30 - 23:00 5.50 10 lOB DRLIN1 Drop survey, TOOH, change out bit & install full guage stabilizer blades, TIH t/1650', no fill. Survey {~ 1624'-3/4 degree Printed: lO/13/98 1:39:25 PM Anadarko Petroleum Page 4 of 17 Operations Summary Report Legal Well Name: Lone Creek #1 ST-1 Common Well Name: Lone Creek #1 ST-1 Spud Date: 6/27/98 Event Name: ORIG DRILLING Start: 6/22/98 End: Contractor Name: Nabors #160 Rig Release: Group: Rig Name: Nabors #160 Rig Number: Sub Date From-To Hours Code Code Phase DescdpfionofOpera§ons 7/12/98 23:00- 00:00 1.00 2 ?.A DRLIN1 Ddll f/1650' t/1660', bottoms uptdpgas 126 units with background gas40 units 7/13/98 00:00- 18:00 18.00 2 2A DRLIN1 Ddll f/1660' t/2098' 18:00 - 18:30 0.50 5 5C DRLIN1 C & C B/U, flow check 18:30 - 19:00 0.50 10 10B DRLIN1 SurVey {~ 2073'-1/4 degree 19:00 - 00:00 5.00 2 2A DRLIN1 Drill f/2098' t/2265' 7/14/98 00:00 - 10:30 10.50 2 2A DRLIN1 Ddll f/2265' t/2550' 10:30-11:00 0.50 5 5C DRLIN1 C & C, flow check 11:00- 11:30 0.50 10 10B DRLIN1 Drop surVey 11:30 - 15:30 4.00 6 6A DRLIN1 TOOH, tight spots {~ 2230', 2171~, 1962' & pump through fight spot {~ 1891'. Clean balled up stabilizers, retdeve survey tool, no surVey 15:30 - 17:00 1.50 6 6A DRLIN1 Change bit, TIH, ream 65' to bottom 17:00 - 18:00 1.00 2 ?.A DRLIN1 Ddll f/2550' tj2576' 18:00-19:00 1.00 5 5A DRLIN1 C & C, check flow 19:00 - 19:30 0.50 10 10B DRLIN1 WL surVey {~ 2553'-1 degree 19:30 - 00:00 4.50 2 2A DRLIN1 Drill f/2576' t/2625' 7/15/98 00:00 - 17:00 17.00i 2 12A DRLIN1 Drlg. 12 1/4" hole from 2625' to 3030' 17:00-17:30 0.50i 5 5B DRLIN1 CBU for wiper tdp to the 13 3/8" shoe. 17:30 - 18:00 0.501 10 10B DRLIN1 Run wireline surVey, no surVey. 18:00-18:30 0.50i 5 15B DRLIN1 CBU Prior to Tdpping' Monitor well. 18:30 - 20:00 1.50. 6 6C DRLIN1 Wiper trip to 13 3/8" shoe. Work thru tite spots from 2945' to 2570'. (newly drilled hole) 30k to 50 k Max. overpull. Pulled to shoe wi no further problem. 20:00 - 20:30 0.50 6 6C DRLIN1 RIH Tite spots from 2500' to 2945'. 40k to work thru rite spots. No fill on ~ottom. 20:30 - 21:30 1.00 5 5B DRLIN1 Circ. and condition mud for Logging. 21:30 - 23:00 1.50 5 5B DRLIN1 Circ. Monitor well, fill trip tank. 23:00 - 00:00 1.00 6 6C DRLIN1 POOH to run wireline logs. 7/16/98 00:00 - 02:30 2.50 6 6C ' DRLIN1 ~OOH to run wireline logs. No hole drag, no swabbing. SLM, (No Corr.) Clean off stabs. 02:30 - 06:30 4.00 11 11J I DRLIN1 ~U and run SWS logs. Run # 1 (AIT-SP-BHC-CAL-GR) Log acceptable, SP poor, being rerun on next two runs. 06:30 ~ 15:45 9.25 11 11J DRLIN1 !Run # 2 (LDT-CNL-CMR-NGS -SP)Log acceptable, hole still in good shape !with no overpull. 15:45 - 19:15 3.50 11 11J DRLIN1 Run # 3 (FMI-GR W/rtealtime dips at wellsite.) FMI failed on trip in hole, POOH replace GR and run in hole. GR above FMI interfered with the signal. 19:15 - 21:45 2.50 11 11J DRLIN1 Run #3 (FMI-GR-with realtime dips at wellsite.) 21:45 - 00:00 2.25 11 11J DRLIN1 Run ~ (RFT-GR-pressure and samples) Calibrate RFT, RIH to warm tool at 7/17/98 100:00 - 05:30 5.50 11 11J DRLIN1 Continue calibrating RFT, RIH, logging. Log acceptable 05:30 - 08:00 2.50 11 11J DRLIN1 R/U for Run #5 (CST) Hold PJSM with SWS. 08:00 - 09:30 1.50 11 11J DRLIN1 RIH with CST, lost communication with tools, POOH 09:30 - 12:30 3.00 11 11J DRLIN1 P/U new CST tool RIH, lost communication with tool, POOH 12:30 - 15:30 3.00 11 11J DRLIN1 Rehead tool conn., RIH Shoot 45 shots. POOH, 43 shots fired 2 failed, full recovery in the 43 fired shots, at the followin depths, 1032'-1 050'-1162'-1357'-1650'-1775'-1782'-1784'-1794'-1870'-1880'-1890'-18 95'-1908'-1910'-1980'-2224'-~6'-2270'-2345'-236E-2404'-2407'-2412'-2418 '-2430'-2443'-2458'-2404'-2557'-2575'-2710'-2745'-2758'-2770'-2780'-2788'-2 950'-2966'-2970%~2'-2~' and 3010. 15:30- 17:30 2.00 6 6C DRLIN1 RIH 17:30 - 18:30 1.00 5 5B DRLIN1 CBU Twice prior to POOH 18:30 - 20:30 2.00 6 6C DRLIN1 POOH to R/U and run 9 5~8" csg. 20:30 - 22:30 2.00 6 6A DRLIN1 Clean and lay down BHA, Break stab blades. , 22:30-00:00 1.50 12 12B DRLIN1 Change top rams to 9 5/8" and rig up to run 9 5/8" csg. Printed: 1~13/98 1:39:25PM file:///Untitled Tommy, I am reviewing the permit to drill package for the LC #2. I have a oouple of questions. --Regarding the downhole disposal plan...your application states that you will set 7" at 5000' and cement it back into the 9-5/8" at 1000'. You then plan to drill to 6000' and oonduct the disposal in that open hole section. You also list the possibility of setting a 5" liner in that hole section. The minimum depth discussed in you disposal request is 3000', but based on your well design (assuming you reach you planned depths) nothing will exit the casing above 5000' and if you are successful in the 6" hole section you may not have any interval to inject in. I would appreciate the opportunity to talk with you and sort this out. I think drilling the tail section of the well and then using it for disposal is not a bad idea, but like I said above what if there is something prospective there? --I would also like to visit regarding the MASP for the hole sections and the casing tests. Our regulations are pretty clear at 25.005(c)(4)(A) that the calculations should be made using a methane gradient back to surface. In your request for the diverter exoeption you talk of the zone that potentially blew out long ago and that you expect it below your 9-5/8" shoe. You have correctly identified that as a hazard but your MASP calculation for that section assumes the shoe fails. That is probably likely, however other operators experience has shown that the earth sometimes is stronger than we give it credit for. T~Falls Creek. I have talked with Paul Mazzolini a couple of times a~ a ans In--t'n-e iast message (whi~~l ndicated that the land people were gettin~_cg____.._~ things sorted out with re sincerely hope that at thi ituation w xpect work to be done on the Falls Creek well to eliminate the surface pressures. I will attempt to call you about 11 am your time on 7/27. Feel free to pop an email back so I can have it in hand when I call. Tom Maunder Petroleum Engineer AOGCC I of I 7/26/00 4:16 PM Lone Creek ~ Diverter Size Waiver Subject: Lone Creek ~ Diverter Size Waiver Date: Tue, 22 Aug 2000 13:01:34 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tommy Thompson <tommy_thompson~anadarko.com>, Peter Leach <peter_leach~anadarko.com> CC: Tom Maunder <tom_maunder~admin.state.ak.us>, Camille Oechsli <cammy_oechsli~admin.state.ak.us>, Dan Seamount <Dan_Seamount~admin. state.ak.us> Tommy and Peter, We have reviewed your request to drill 12-1/4" hole thru a diverter having a 10" side outlet. We reviewed the nearby wells and conclude that shallow gas - above 1000' - is to-be-expected in that area. We also reviewed the Mobil Moquawkie #1 well drilled in 1965 which blew out while pulling out from 1525' Based on the above reviews, we deny your request to drill thru the diverter with a bit size larger than the diverter spool side outlet. Sincerely, Blair Wondzell, 8/22/00. 1 of 1 $/22/00 I:01 PM NOTE TO FILE Date: August 22, 2000 In Re: Lone Creek #2 (PTD 200-108) Discussion Regarding Disposal Plan On July 27, 2000 I sent a note to Tommy Thompson of Anadarko with some questions regarding their waste fluid disposal plan contained in the Lone Creek #2 permit application. As submitted, the discussion was confusing. A copy of that note is attached. A meeting was held on July 31 with Tommy Thompson. Thompson stated that they drafted the disposal application based on setting the 7" casing no shallower than 3000'. Any injection is planned to be below 3000'. The exact setting depth of the 7" could be as deep as 5000' depending on what is found as the 8-1/2" hole is drilled. If prospective pay intervals are found deeper than 3000', the intent is to dispose of fluids in deeper non-pay intervals. Anadarko intends to use the same procedure employed on the Lone Creek #1. When drilling operations are completed, deeper sections of the open hole would be plugged according to regulations, a retainer would be set above the casing shoe, drill pipe stung in and the fluids would be pumped below the retainer into the remaining open hole section. At the conclusion of pumping, cement would be pumped to seal the casing shoe and complete abandonment of the deep wellbore sections. If Anadarko is successful in finding payzones in all hole sections and sets their deep liner, an identified disposal interval would have to be accessed by perforating. A retainer would be set above the perfs and fluids would be pumped through the drill pipe. 200-108LoneCrk#2072700.txt Subject: RE: Lone Creek #2, et al Date: Thu, 27 Jul 2000 10:33:02 -0500 From: Tommy Thompson <tommy_thompson@anadarko. COM> To: "'Tom Maunder'" <tom maunder@admin.state.ak.us> > ..... Original Message ..... > From: Tom Maunder [SMTP:tom maunder@admin.state.ak.us] > Sent: Wednesday, July 26, 2000 4:49 PM > To: Tommy Thompson > Cc: Blair Wondzell > Subject: Lone Creek #2, et al > > Tommy, > I am reviewing the permit to drill package for the LC #2. I have a > couple of questions. > > --Regarding the downhole disposal plan...your application states tha t > you will set 7" at 5000' and cement it back into the 9-5/8" at 1000' > You then plan to drill to 6000' and conduct the disposal in that ope n > hole section. You also list the possibility of setting a 5" liner i n > that hole section. The minimum depth discussed in you disposal requ est > is 3000', but based on your well design (assuming you reach you plan ned > depths) nothing will exit the casing above 5000' and if you are > successful in the 6" hole section you may not have any interval to > inject in. > I would appreciate the opportunity to talk with you and sort this ou t. > I think drilling the tail section of the well and then using it for > disposal is not a bad idea, but like I said above what if there is > something prospective there? > Page 1 200-108LoneCrk#2072700.txt > --I would also like to visit regarding the MASP for the hole section S > and the casing tests. Our regulations are pretty clear at > 25.005(c) (4) (A) that the calculations should be made using a methane > gradient back to surface. In your request for the diverter exceptio n > you talk of the zone that potentially blew out long ago and that you > expect it below your 9-5/8" shoe. You have correctly identified tha t as > a hazard but your M_ASP calculation for that section assumes the shoe > fails. That is probably likely, however other operators experience has > shown that the earth sometimes is stronger than we give it credit fo r. > Tom Maunder Petroleum Engineer AOGCC << File: Card for Tom Maunder >> Page 2 TO: FROM: SUBJECT: ii' Petroleum Corporation Inter-Office Correspondence P. Leach/T. Thompson August 2, 2000 M. P. Globe Formation water salinities on the Moquawkie Anticline Attached are formation water analyses on two wells on the Moquawkie Anticline, the Simpco E. Moquawkie #1, and the Lone Creek #1st1. In these two logs, formation water resistivity has been calculated with two different methods, the Rwa method, and the Rw from SP. Rwa is a technique that calculates apparent formation water resistivity from computed log porosity and measured formation resistivity using the Archie relationship Ro=Rw/Phim' where Ro is the resistivity of the water saturated formation, Rw the formation water resistivity, Phi the formation porosity, and m the cementation exponent. In the Rwa technique, the solution to this equation yields Rwa =Rt* Phim (Rt is the true formation resistivity). Phi can be calculated from density, neutron, and/or sonic logs, Rt is measured with a resistivity device, and m must be either measured from core, or inferred from rock type. In the case where formations are fully water saturated, Rwa is a close approximation of true formation resistivity, and thus salinity. In hydrocarbon bearing zones, the Rwa technique will yield an apparent formation water resistivity that is higher than true formation water resistivity. In these analyses, Rt was taken from the deep resistivity measurement, and porosity was calculated using the density/neutron crossplot technique. The exponent m was assumed to be equal to 1.8 based on cuttings descriptions that indicate that the formations penetrated are slightly to moderately consolidated. The cementation exponent, m, is a function of a number of formation characteristics that affect the tortuosity of the resistivity paths in the rock. Typically, as formation consolidation/cementation increases, m increases. The world-wide average for m is very close to 2. The Reservoirs Inc. World Wide rock catalog has measured m values from over 40 cores. In this catalog, m ranges from a minimum of 1.68 to a maximum of 2.26, with a mean value of 1.93. Increasing m will decrease the calculated Rwa value. The Rw from SP method uses the equation SSP=-Klog(Rmfe/Rwe), where SSP is the static spontaneous potential value, K a temperature based constant (K=61+.133*Temperature), Rmfe the chemical activity equivalent of drilling mud filtrate resistivity, and Rwe the chemical activity equivalent of formation water. Methods for converting from Rwe and Rmfe to Rw and Rmf respectively are documented in the Schlumberger Log Interpretation Chart #SP-2. The Rw from SP method is complicated by the SP measurement's inability to resolve thin zones, suppression of SP response in Iow permeability and hydrocarbon bearing intervals, the accuracy (or lack thereof) of the Rmf value, and the presence of SP baseline drift. Sp baseline drift is a problem that is particularly bad in the Cook Inlet area where good SP grounds are difficult to attain. For the Rw from SP calculation presented in this report, SP curves were baseline shifted to remove drift, and Rw was calculated using Rmf values reported on the Schlumberger log headings. The attached logs (figures I and 2)include computed shale volume (curve name VSH), baseline shifted SP (curve name SBL), Rwa (Curve name RWA1.8), Rw from SP (curve name RWSP), and resistivity curves. Rwa has been calculated in the sands only. Also included on the plots is a curve labeled "LIM". This curve denotes the resistivity equivalent of a 3000 ppm NaCI brine versus depth. The resistivity equivalent value decreases with depth due toincreasing formation temperature. Resistivity is inversely proportional to salinity, so a decreasing Rwa value corresponds to an increase in salinity. In those places where the Rwa and RWSP curves are to the left of the LIM curve, the zones have formation water salinities in excess of 3000 ppm NaCI equivalent. The match between Rwa and RWSP in the Lone Creek #1 st1 is exceptionally good, particularly taking into account the relatively poor quality SP curve from this well. In the Simpco E. Moquawkie #1, the Rwa and RWSP curves track each other well, but there is an offset between the two curves that is consistent throughout the well. This is most likely due to an incorrectly reported Rmf value on the log heading. An additional RWSP curve with the curve mnemonic RWSP.5, was calculated for this well, assuming that the Rmf value was off by a factor of two (a large but not unusual error, particularly with this vintage log). This adjusted RWSP.5 curve is in good agreement with the Rwa value computed in the well. It should be noted that the Rw from SP values are valid only in the permeable intervals. Impermeable intervals will have no or little SP deflection. To further corroborate the calculated formation water resistivities, our files were searched for measured formation water resistivity and salinity values. Attached are copies of the water analysis reports on zones in both wells. An RFT in the Lone Creek #1 stlrecovered water from 5589.5', with a salinity of 25,300 to 31,700 ppm Chlorides (approximately 46,000 ppm NaCI equivalent) with resistivity of .125 to .111 Ohm-m at 66F. Based on the high Potassium content in this water, it is probably highly contaminated with drilling mud filtrate. A somewhat more conclusive result was attained from a DST done in the Simpco E. Moquawkie #1 over the interval from 8490 to 8512. This test yielded water with NaCI equivalent concentrations in the range of 6382 ppm to 6650 ppm, and resistivity values in the range of 1.06 to 1.1 ohm-m. Expanded plots of the two wells over these intervals (figures 3 and 4), comparing the recovered water resistivity values to those calculated from SP and Rwa techniques are included here. On Figure 3, the plot of the Lone Creek #1, the temperature adjusted recovered water resistivity is represented by the curve named RWRFT. On Figure 4, the plot of the Simpco E. Moquawkie #1, the temperature adjusted recovered water resistivity is represented by the curve named RWDST. Copies of the formation water analyses are also attached. It should also be noted when considering the issue of contamination of the fresh water table on the Moquawkie anticline, that the Lone Creek #1 encountered what Anadarko believes to be gas charged sands in sands as shallow as 1000'. It is evident from the attached figures, that the Rwa, RWSP, and produced water data and interpretations are corroborative, and that at a minimum, from the top of the "C Marker" stratigraphic section down, all water-saturated sands have formation water salinities well in excess of 3000 ppm NaCI. Those sands within these sections that exhibit Rwa values above the 3000 ppm line are fully or partially gas saturated. /~ word about the Lon~'~" ';reek #1 st1 to stem (hopefully) ar(~" ,otential confusion: Due to drilling difficulties, the Lone Creek #1 well was sidetracked below the interval included in this analysis, and below the depth at which the RFT that is the source of the attached water analysis was run. Both the Lone Creek #1 and the Lone Creek #1st1 are exactly the same well bore through the interval interpreted in this report. Because our digital log database is more complete in the Lone Creek #1 st1 version of the data, this "well" was used for the petrophysical interpretation. Please contact me with any questions or comments. Lofie Creek ~ Diverter Size Waiver Subject: Lone Creek ~ Diverter Size Waiver Date: Tue, 22 Aug 2000 13:01:34 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tommy Thompson <tommy_thompson~anadarko.com>, Peter Leach <peter_leach~anadarko.com> CC: Tom Maunder <tom_maunder~admin.state.ak.us>, Camille Oechsli <cammy_oechsli~admin.state.ak.us>, Dan Seamount <Dan_Seamount~admin.state.ak.us> Tommy and Peter, We have reviewed your request to drill 12-1/4" hole thru a diverter having a 10" side outlet. We reviewed the nearby wells and conclude that shallow gas - above 1000' - is to-be-expected in that area. We also reviewed the Mobil Moquawkie #1 well drilled in 1965 which blew out while pulling out from 1525' Based on the above reviews, we deny your request to drill thru the diverter with a bit size larger than the diverter spool side outlet. Sincerely, Blair Wondzell, 8/22/00. 1 of 1 8/22/00 1:01 PM USDW Protection Geologic Prognosis Lone Creek #2 Properly cemented surface casing will protect USDW's that have salinity of less than 3,000 PPM. Well log analysis indicates all water-saturated sands below the top of the "C" marker have formation water salinities above 3000 ppm NaC1. In Lone Creek #2, the estimated top of the C marker lies at 2093' measured depth (MD). Drilling waste will be injected into a thick, Middle Tyonek sandstone section that extends from below the 7" shoe (at a minimum MD of 3000') to the projected total depth of the well (between 5,000' and 6,000~ MD). The confining zone will consist of a minimum of 907'of Middle Tyonek shale and coal that lie between 2093'and 3000' MD. Steve Davies August 11, 2000 State of Alaska Division of Governmental Coorl; http ://www.gov. state, ak. us/dgc/oilgas/o&g2, html ,a k,~' m~ ,m ..,,. ..... , · %?..' ' · ' . . *'" ..;, '?' ' '..,,,..... ACMP Home I State Home I Governor Home I DGC I Coastal Map lOll and Gas Repo~s I Report As of '~.,',~ ':~~'-'~;! ' Glenn Gray and Riki Lehman of the Division of Governmental Coordination (DGC) prepare this report twice each month to provide up-to-date information about state oil and gas reviews. Contact Glenn Gray at 907-465-8792 or via Email at ,Cllenn ,qray@,,q_ or.state.ak.us if you have any questions about this report or if you have news items of interest to be included in the next update. Riki Lehman may be contacted at 907-271-4317. This report and back issues of the Oil and Gas Reports can be found at: .http://www.,q ov. state, a k. us/dgc/oilgas/reports, html Recent News P_rojects in Review Reviews Completed Pre-Application Staqe Lease Sales Other News ili!'"'~l, "' .','",t ........ "" I1~""I" .... It,Iii Iii ......... I'! ii !~¢'II, 1 of 7 * DGC initiates review for Anadarko's Moquawkie Prospect on the west side of Cook Inlet * Forest Oil to Buy Forcenergy Back to the top. Next: Proiects in Review Moquawkie Prospect (,nadarko): Anadarko proposes to drill a new oil and gas exploration well,~~nd re-enter the Mobil Moquawkie ¢1 well on the West Side of Cook Inlet. Access would originate from the Tyonek Village road system to the access road for the Lone Creek feet of new road at each location. The land is owned by Tyonek with subsurface rights by ClRI. D~ initiated this review on July 27. 8/22/00 12:03 PM State of Alaska Division of Governmental Coor!' ';- '- Review Status: Request for Information: August 22, 2000 Comment Deadline: August 31, 2000 Proposed Consistency Determination: September 12, 2000 (on or before) Final Consistency Determination: .~.eiatl~q~l~..er-.~$8~000~(~0~~k~m)~: http ://www. gov. state, ak. us/dgc/oilgas/o&g2, html Grassim Oskolkof #1 Exploration Well (Marathon): This exploration project involves drilling a gas exploration well nine miles north of Ninilchik. An existing private road will be extended 1,500 feet using an existing on-site gravel pit. Marathon plans to drill a water well for use during drilling. DGC initiated the consistency review on May 1, extended the review deadlines on June 13 for an information request, and restarted the review on July 28. Review Status: Proposed Determination: August 7, 2000 (on or before) Final Determination: August 15, 2000 (on or before) Milne Point Unit/Kuparuk Formation (BP): BP proposes to construct a new pipeline to transport natural gas liquids from the existing Oliktok pipeline to processing facilities at Milne Point. The tie-in location for the Milne Point pipeline will be at the intersection of the Spine Road and the Milne Point Road at Module 68, a small module that currently houses leak detection equipment. The new pipeline will be installed on existing VSMs and will be designed to accommodate "smart pigs" with temporary "pig launchers" at either end of the pipeline. The pipeline will terminate at a new NGL transfer metering module (Module 48) that will be installed as part of this project. The project also includes pipelines to individual wells within the unit. DGC started the original review for this project on August 26, 1998 and stopped the review clock on October 9, 1998. DGC initiated a new review on May 5, 2000 and extended the request for additional information deadline without extending the remaining review milestones. Review Status: Comment Deadline: August 1, 2000 Proposed Consistency Determination: August 11, 2000 (on or before) Final Consistency Determination: August 17, 2000 (on or before) Nikiski Refinery NPDES Permit (Tesoro): EPA and the state have begun their review for the renewal of the NPDES permit and the DEC 401 certification for the Tesoro refinery. This review addresses water discharges associated with operation of the refinery. DGC initiated the consistency review on May 23 and extended the remaining review deadlines on July 4 to provide additional time to consider public comments. Review Status: Request for Information: Deadlines Extended Back to the top Next: Reviews Completed ..... { '{ i,{~i {{ ' 2 of 7 8/22/00 12:03 PM State of Alaska Division of Govemmental Coorc~? ';^~ http ://www.gov. state, ak. us/dgc/oi l gas/o&g2, html Halliburton Pad Expansion of Shop & Explosive Storage Magazine (Halliburton): This project, located in Deadhorse, involves filling less than 0.20 acres of wetlands to expand an existing gravel pad within an existing lease. DGC initiated the consistency review on started May 23, and DGC issued a final consistency determination on June 28. Back to the top Next: Pre-Application Stage NPRA Winter Exploration Drilling - Trailblazer Well (BP): BP plans to initiate a 5-year exploration drilling program this coming winter on a Phillips Alaska lease. This project involves an onshore ice road of 16 to 24 miles, an ice airstrip, and support camps. The exploration period will extend from December 15 to May 15 of each year. New pipes & VSMs at Eileen West End (BP): This project involves installation of a 12" line for produce water and a 10" line for miscible injectants along existing vertical support members from the Gathering Center 2 pad to the Eileen West End (EWE) junction near W pad. At W pad, a new pipeline with new VSMs will be installed to support a 12" produced water line on a southerly route to Z pad. At the EWE Junction, the new portion of the miscible injectants line will end and the miscible injectants will be distributed to W pad and Z pad via an existing 8" line. DGC held a pre-application meeting on July 18, 2000. Flaxman Island Reserve Pit Closures A-1 and G-2 (BP): ExxonMobil Production Company has contracted with Fairweather E&P Services to obtain permits for disposal of approximately 15,000 cubic yards of drilling waste from the Flaxman Island reserve pit. One alternative under discussion is to drill an on-site disposal well for the waste. The work is to be substantially completed by May 1, 2001. Erosion of the island threatens to undermine the reserve pit. Gas to Liquids Test Facility (BP): This Gas to Liquids Test Facility (GTL-TF) would convert approximately three million standard cubic feet per day of natural gas into an estimated three hundred barrels per day of synthetic crude (light hydrocarbon liquids). The project site is a 23 acre parcel located at Mile 20 on the North Kenai Road south of the Tesoro Refinery and southeast of the Agrium Fertilizer Plant in Nikiski. BP plans to begin site preparation during the fourth quarter of 2000. DGC expects to initiate the review in the near future. West Dock Head Maintenance No.2 & 3 (Phillips): The company proposes to dredge seafloor sediments at these dock heads to facilitate use of the docks for moving rig components, support equipment, and materials to the Northstar Development Project. Fuel Gas Line Repairs (Alyeska): The company is requesting 27 sites to be added to the existing land use permit. Each site will need a 3 of 7 8/22/00 12:03 PM State of Alaska Division of Governmental Coor,~:" ,ti,-,, http ://www.gov. state, ak. us/dgc/oilgas/o&g2, html 50 x 200 foot-long land use area for stabilization fill. The fill will be used for depressions extending outside the existing right of way. The total area of fill comprises 3.4 acres on all sites, both state and federal land, from milepost 12 to 140. DGC is working to determine if this activity will need an ACMP review. Kuparuk Industrial Center's Secondary Containment Area (Phillips): The containment area will be built to contain the maximum capacity of a vacuum truck plus 10% (330bbls). The foundation will consist of concrete supports, and a new gravel fill area will provide a safe truck turnaround. An area of 200 feet by 90 feet (0.4 acres) will be filled with 2,800 cubic yards of gravel. The Corps may decide to do an "in house" modification of their permit. Schrader Buff Development (BPXA): BPXA will be holding pre-application meetings to discuss using exisiting infrastructure at the Milne Point Unit (MPU) for drilling up to 100 wells and constructing one pad (S Pad) for drilling up to 70 wells by using multilaterial drilling technology. Total estimated reserves are 200 to 300 million barrels. Meltwater Oil Field (Phillips): Phillips Alaska Inc and BP Exploration (Alaska) announced a discovery at their Meltwater prospect. The companies estimate about 50 million barrels of recoverable reserves. Meltwater is located about ten miles south of the Tarn reservoir that is located south of the Kuparuk Unit. Phillips is working on permit applications. Spill Preparedness Permits (Alaska Clean Seas): Alaska Clean Seas proposes to consolidate permits for spill response on the North Slope. The consolidation involves a number of Army Corps of Engineers permits. DGC is awaiting more information from the applicant before initiating this review. McCovey Prospect (Phillips): In cooperation with ARCO, DGC sponsored a pre-application meeting on March 31 for a proposed offshore exploration project next season. Phillips has decided to use an ice island for drilling rather than the CIDS. The site is located in the Outer Continental Shelf about seven miles northwest of Cross Island in about 45 feet of water. A preapplication meeting on august 16 will address proposed changes to the project. Glenn Gray will coordinate this review. Nikolaevsk Oil and Gas Exploration Wells (Gas Pro): DGC sponsored a preapplication meeting on March 29 for a proposed oil and gas exploration well near Anchor Point on the Kenai Peninsula. For more information about this project, contact Riki Lebman at 907-271-4317. Anadarko proposes to drill an oil and gas well on private land owned by the Tyonek Land with subsurface rights by CIRI. The project involves a 1.6-mile gravel road and a 300 x 400' pad. DGC held a preapplication meeting for this project on March 29. Redoubt Shoals Production Facility (Forcenergy): DGC is awaiting receipt of the application packet from Forcenergy for development of the Redoubt 4 of 7 8/22/00 12:03 PM State of Alaska Division of Govemmental Coor(~: q,,", http ://www. gov. state, ak. u s/dgc/o i l gas/o&g2, html Shoals reservoir. The project would involve construction of a pipeline from the proposed Osprey Platform to a land-based processing facility on Salamatof Corporation land in the vicinity of the proposed Tom Cat exploration site. If Spring 2000 exploration drilling confirms a commercial reservoir, Forcenergy hopes to begin construction of production facilities during summer 2000 and begin production in fall 2001. On May 15, the State presented its oral argument to the Superior Court regarding the lawsuite by Cook Inlet Keeper for the Redoubt Shoals exploration project. Cross Cook Inlet Pipeline (Unocal): Unocal postponed public meetings on this project until completion of partnership agreements. The proposal involves construction of an oil pipeline across Cook Inlet in conjunction with a phase out of the Drift River terminal. Unocal is considering several routes from the West Side of Cook Inlet to Nikiski, and it will likely propose a route from Granite Point to Nikiski. The pipeline would be ten-inches in diameter with a thickness of .7 inches and with a coating of about 2 inches of concrete. Unocal is currently in negotiation with potential partners and has postponed public meetings associated with this project. Pike Prospect- Cross Island (Phillips): On December 7, 1999, DGC sponsored a pre-application meeting for Phillips Petroleum's Pike Prospect which is located in the Cross Island area of the Beaufort Sea. The proposal may include a three-year exploration program in addition to a seismic survey. Clearwater Environmental, agent for Phillips, submitted a report to DEC on modeling protocol for this project on January 27. The project will not likely begin until the 2001-2002 season. Stariski Prospect (Frontier Petroleum): This proposed exploration oil and gas well would be located in the Ninilchik Dome area of the Kenai Peninsula. Cook Inlet Oil Pipeline Tyonek Deep Project (Phillips Petroleum): A change in the route would result in the pipeline following the existing pipeline from the Tyonek A platform through the existing right-of-way to overland to Unocal's Granite Point facility. Liberty (BPXA): DGC is working with state agencies to develop a plan for the coordinated state review for the Liberty Project. Since the island location is in federal waters, there would be fewer state permits involved than what was required for the Northstar Project. Although BP has already submitted many permit applications for this project, it is still considered in the "pre-application stage" until the ACMP review begins. The MMS will establish a timeframe for the draft and final ElS after submittal of studies this fall. BP expects to begin production in 2003. The ElS team is currently developing alternatives and a cumulative impacts analysis for the draft ElS. A study, currently in progress by BP and Intec, will analyze pipeline design alternatives. The MMS is currently revising the ElS schedule. Back to the top Next: Lease Sales 5 of 7 8/22/00 12:03 PM State of Alaska Division of Governmental Coorl.:-" *tir'm http ://www. gov. state, ak. u s/dgc/oilgas/o&g2.html Copper River Exploration License: The DNR solicited comments on a preliminary best interest finding for a Copper River Oil and Gas Exploration License. If DNR decides to issue the license, bids are scheduled to be opened on August 26, 2000. Contact the DNR Division of Oil and Gas for more information about this license at 269-8800. State Cook Inlet Areawide: As a result of the DNR Call for New Information for the planned August 16, 2000 Areawide oil and gas lease sale, DNR will usse a supplement to Chapter Three of the Best Interest Finding on May 2, 2000. Contact the DNR at 269-8800 for more information about this sale or consult the Division of Oil and Gas web page: http://www, doq.dnr, state.ak, us/oil/ On May 16, DNR removed 126 tracts from this sale in response to a Superior Court decision regarding beluga whale habitat. State Beaufort Sea Areawide (Barrow to Canada Border): DNR issued the final best interest finding and the final consistency determination on July 15, 1999. The sale, originally scheduled for October 13, 1999, was postponed, and it is expected to be held during November, 2000. On March 8, 2000, DNR issued a Call for New Information. You may view the final best interest finding at: http://www, doq.dnr, state.ak, us/oil/ or contact James Hansen at for new information. State North Slope Areawide (Onshore Colville River to Canning River): DNR issued the final finding for this sale area on March 17, 1998 and issued a Call for New Information on May 28, 1999. The sale is expected to be held in November, 2000. For more information, contact DNR at 269-8800. State North Slope Foothills Areawide: A September 9, 1999 request for information from agencies, local governments and Native corporations requests information by January 10, 2000 about social, economic and natural resource values. The preliminary best interest finding is scheduled for July 2000, a final finding in January 2001, and the sale during May 2001. OCS Lease Sale 176: On January 6, 2000 the MMS sponsored the first meeting of the Alaska Offshore Advisory Committee. Committee members discussed initial thoughts about the sale. On May 26, 2000, MMS decided to postpone a decision on the Area Identification for this lease sale. LS 176 is a proposed sale for the Beaufort Sea. Back to the top Next: Other News Eider Critical Habitat Proposed Rule: The U.S. Fish and Wildlife Service (FWS) is seeking comments on proposed rules to establish critical habitat for Steller's and spectacled eiders. The FWS comment deadline has been extended to June 6 of 7 8/22/00 12:03 PM State of Alaska Division of Governmental Coorfd:" q.ti,nn { http://www.gov.state.ak.us/dgc/oilgas/o&g2.html 20, 2000 for the spectacled eider proposal and Steller's eider proposal. The state has requested an extension of the comment deadline until the public has had adequate time to review an economic analysis that the FWS is currently developing. Forest Oil Buys Forcenergy: Forest Oil Corporation and Forcenergy have agreed to merge their companies. The new company, Forest Oil Corporation, will be headquartered in Denver. The company plans to continue its presence in Alaska. Back to the top Last modified August 3, 2000 Send comments and suggestions to our V~bworker: Sydney Mitchell~..qov. state.ak.us. Send comments and suggestions to the Oil & Gas Report author: Glenn Gray 7 of 7 8/22/00 12:03 PM ~one Creek #2, et al Subject: Lone Creek #2, et al Date: Wed, 26 Jul 2000 16:49:06 -0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> Internal To: Tommy Thompson <tommy_thompson@anadarko.com> CC: Blair Wondzell <blair_wondzell~admin. state.ak.us> Tommy, I am reviewing the permit to drill package for the LC #2. I have a couple of questions. --Regarding the downhole disposal plan...your application states that you will set 7" at 5000' and cement it back into the 9-5/8" at 1000' You then plan to drill to 6000' and conduct the disposal in that open hole section. You also list the possibility of setting a 5" liner in that hole section. The minimum depth discussed in you disposal request is 3000', but based on your well design (assuming you reach you planned depths) nothing will exit the casing above 5000' and if you are successful in the 6" hole section you may not have any interval to inject in. I would appreciate the opportunity to talk with you and sort this out. I think drilling the tail section of the well and then using it for disposal is not a bad idea, but like I said above what if there is something prospective there? --I would also like to visit regarding the MASP for the hole sections and the casing tests. Our regulations are pretty clear at 25.005(c) (4) (A) that the calculations should be made using a methane gradient back to surface. In your request for the diverter exception you talk of the zone that potentially blew out long ago and that you expect it below your 9-5/8" shoe. You have correctly identified that as a hazard but your MASP calculation for that section assumes the shoe fails. That is probably likely, however other operators experience has shown that the earth sometimes is stronger than we give it credit for. The last item is the et al...Falls Creek. I have talked with Paul Mazzolini a couple of times and sent emails to both him and yourself. To date, I have only been received replies from Paul. I am disappointed that neither Blair nor I have received any communication from you regarding this well. Even a short note acknowledging receipt of my messages and that you or your staff were working on the plans would have been appreciated. In the last message (which I think you got a copy of) Paul indicated that the land people were getting things sorted out with regard to the operatorship and that non-rig and rig options were being prepared. I sincerely hope that at this late date plans are well beyond being prepared and that sorting out the land situation hasn't severely impacted your ability to accomplish work on that well this season. The beginning of August is fast approaching and I believe we have been most clear in our expectation that we expect work to be done soon on the Falls Creek well to eliminate the surface pressures. I will attempt to call you about 11 am your time on 7/27. Feel free to pop an email back so I can have it in hand when I call. Tom Maunder Petroleum Engineer AOGCC I o£2 7/31/00 1:22 PM JUL-26-O0 WED 10',16 ~I"I OIRI Re~l Esta~t,e FAX NO, 907 263 5190 P, O1 I R I Cover Sheet TO: Steve Davies FAX #: 276-7542 FR: Luke Boggess DT: CiRI Land Dept PAGES: 2 (w/cover) Comments: Steve, here is a map reflecting the lease situation at Moquawkie, I will be sending a color version by mail shortly. It~ you have any questions or comments let Candace or me know. Thank.~ Luke Boggess Land & GIS Special[st 265-4527 Iboggessez~ciri.com The information contained in this facsimile transtaR[al is k~tended only for the addressee or the addressee's au[horized agent, The message may contain infom]a ~ion ~hat is privi/e, ged, confMc'ntial, or otherwise exemp[ from di.¢ck~s,.tre, If the reader or,his informaEon i~ no~ [he in~ended recipient, or reciplent's agent, you are hereby notified that any dissemination, distrilaution or copying of tiffs information is strictly prohibited, ff yolJ have received this h~fom~ation in error, please notify th(: ,¢ender immed?,.; rely lay telephone and rezun~ the origin,~l information to the sender, by U.S. mail, at Lhe addre$3' below. NOTE: If there are any problems with this transmis$ion~ please call (907) 274-8638. 2525 "C" STREET, SUITE .500 · P.O. BOX 93330. ANCIIOIL&GE, ALASKA (907) 274-8638 · F~X (907) 263-5183 · Web $~tc: ~v, citi.com JUL-26-O0 IdED 10'16 RN OIRI Real Es~a~e T13N P,' C-'061,~ NO, Tt3N R011~ 907 263 5190 P, 02 Beluga River' Unit~. . R~OW T¥onek Oil & Gas Leases r'-I Phillip's Alaska, Inc; 50% r'-I Anadarko Petroleum Corp.: 50% ~ ' t Oil & Gas Units < ,,.4 Village Subsurface t:~:i::t.', Village Surface. C IRI Subsurface ~'~', CIR! Surface CIRI Subsu~ace k,,.~ CIRt Su~ace & Subsu~ace Miles I Moquawkie Oil & . ,,, ,, --. ......................... ANADARKO PETROLEUM CorPORAT~ 17001 NORTHCHASE DRIVE · P.O, BOX j,, ..~O TEL. {281) 875'1101 · HOUSTON, TEXAS 77251-1330 July 20, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Steve Davies Re: Additional attachments (Color Copies) APD Filing for Lone Creek No. 2 Enclosed please find the additional attachments you requested for Anadarko's APD filing pertaining to the Lone Creek No. 2. Included are color copies of the Pressure Profile Data (mud weight versus depth - proposed & offsets) and the Water Salinity Log Interpretation Data. Should you require additional information, please contact me at (281) 874-3262. Should I be unavailable, please call Susan Hathcock at (281) 874-8758. The other information regarding lease ownership verification and designation of operatorship is forthcoming. Sincerely, hompson Drilling Superintendent Cc: Susan H Gracie S. Attachments JUl_ 2 4 2000 ,~aska Oi,; & Gas .... ,'" ,A.~chora~e LONE CREEK #1 ST1 Figure 2 Figure 3 Figure 4 TO: FROM: SUBJECT: Petroleum Corporation Inter-Office Correspondence P. Leach/T. Thompson M. P. Globe Formation water salinities on the Moquawkie Anticline July 11, 2000 Attached are "Rwa" analyses on two wells on the Moquawkie Anticline, the Simpco E. Moquawkie #1, and the Lone Creek #1 st1. Rwa is a technique that calculates apparent formation water resistivity from computed log porosity and measured formation resistivity. In the case where formations are fully water saturated, Rwa is a close approximation of true formation resistivity, and thus salinity. In hydrocarbon bearing zones, the Rwa technique will yield an apparent formation water resistivity that is higher than true formation water resistivity. The attached plots include computed shale volume, sp, Rwa, and resistivity curves. Rwa has been calculated in the sands only. Also included on the plots is a curve labeled "LIM". This curve denotes the resistivity equivalent of a 3000 ppm NaCl brine versus depth. The resistivity equivalent value decreases with depth due to increasing formation temperature. Resistivity is inversely proportional to salinity, so a decreasing Rwa value corresponds to an increase in salinity. In those places where the Rwa curve is to the left of the LIM curve, the zones have formation water salinities in excess of 3000 ppm NaCl equivalent. It is evident from these two logs, that from the top of the "C Marker" stratigraphic section down, all water-saturated sands have formation water salinities well in excess of 3000 ppm NaCI. Those sands within these sections that exhibit Rwa values above the 3000 ppm line are fully or partially gas saturated. Please contact me with any questions or comments. FRAC Simpco E. MoquawNie #~ RMF F[~IFT IBHT I RWA~ L~M .5~* LONE CREEK #1 ST1 Lone Creek #2 Moquawkie Prospect Pressure Profile I3-3/8" j ~,~. i-~ ~ estimated pore press , i %__ ........ proposed mud weight , { ~ calculated frac grad ~ooo a ~" ~ ~ .......... ~ ~ ~ro~o~e~ ~ ¢~ 1~18' -~Tyonek 2000 3O00 I~ 4000 5OOO 600O 7OOO 8000~ 9 10 11 12 13 14 15 Equivalent Mud Weight(ppg) S:~laska~Driltin§\Lone C~ek 2~ressure profile LC 2xls p~ssure p~file 16 17 18 19 fi ;ch(Taqe 0 1¢8'- Beluga 13-3/8" 1 o00 1 ~,18' -i Tyonek 2000 'C' MaFk~r 3000 N 4218' 'E' MarkSr 5000 6000 7000 ~ ~ ~ / 8O0O ~ ~-4000 Lone Creek #2 Moquawkie Prospect Pressure Profile 8 9 10 11 12 13 14 15 Equivalent Mud Weight (ppg) S:tAlaska\Drilting\Lone Creek 2\pressure profile LC 2xls pressure profile estimated pore press proposed mud weight calculated frac grad proposed csg pts 16 Lone Creek #2 Moquawkie Prospect Offset / MW vs Depth 2000 40oo 60O0 8000 10000 12000 Simpco Moquawkie #1 Simpco Moquawkie #2 Mobil Moquawkie #1 Mobil Moquawkie #2 Superior 3 Mile Creek Simpco Moquawkie #1 RFT Data Simpco Moquawkie #2 RFT Data Mobil Moquawkie #1 RFT Data Simasko E Moquawkie #1 RFT Data --APC Lone Creek #1 14OOO 16000 ! i _-q 8 9 10 11 12 13 Mud Weight(ppg) moquawkie-nephaline offset Pressure Profile (2) 7/7/00 14 15 16 17 t8 ANADArKO PEtrOLEUM COR PoR~] , ION 17001 NORTHCHASE DRIVE 1330 TEL. 1281} 875-1101 · HOUSTON, TEXAS 77251-1330 nadaH July 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Mr. Blair E. Wondzell, P.E. Application for Oil and Gas Exploration Spacing Exception Lone Creek #2 (Sec. 30, T12N, RllW) Dear Mr. Wondzell: Anadarko Petroleum Corporation (Anadarko) requests a spacing exception in accordance with the requirements in 20 ACC 25.055 for its planned Lone Creek #2 exploration well in the Moquawkie prospect located on the west side of the Cook Inlet. This is a vertical well located at 1956 FNL and 199 FWL of Sec. 30, T12N, RllW. It is within 500' of a quarter section line for a potential oil discovery and 1500' of a section line for a potential gas discovery. Enclosed is a surface location plat for this well and any known wells in the immediate area. Anadarko operates the leases on the adjacent and diagonal quarter and section drilling units and are equal partners in all units with Phillips Alaska, Inc. As such, no registered notification is necessary. I am acquainted with the above facts and verify that those facts are true and that the plat correctly portrays pertinent and required data for this request. If there are any questions, please contact either Tommy Thompson at 1-281-874-3262 or myself at 1-281-874-8758. Sincerely, Susan Hathcock Coordinator, Regulatory Affairs and Safety TT :nl Enclosures (1) { 58" ' $ 88' ~ E 4993.86 N 2599638.13 E 268416.33 N 2599539.50 E 275406.21 ROAD PROPOSED ' CULVERT ~198.83' LONE CREEK ALT. PAD #2 N 2597684.00 E 268579.00 SEC. ,50 SCALE 1" = 1000' 50 31 N 2594359.39 E 268310.71' N 2594260.50 E 275517.91 N 88'51'11" W 5008.17' 1'9 120 o o z 31 32 VICINITY MAP N.T.S. NOTES 1. DATE OF SURVEY MAY 21, 2000. 2.REFERENCE FIELD BOOK FRB 97-04 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD27. 4. HORIZONTAL CONTROL I$ BASED ON MONUMENTS CPI-ID AND CP2-1D. ~.' '.~1 ~C... -. . f '1,%,"-. .."-¢ ~ LEGEND -~ AS-STAKED WELL CONDUCTOR LOCATED WITHIN PROTRACTED SEC. .36, T 12 N, R 11 W, SEWARD MERIDIAN, AK. ANADARKO LONE CREEK WELL #2 Robert 801 W. FIREWEED LANE , ANCHORAGE, AK 9950.3-1801 DATE: 6/20/00 SCALE: 1"=1000' JDRAWN: JCLB RAT[: CHECK: GTB APPROVAL: I FRB IANADARKO! J SHEET: I 1/1 JOB#: 2000271 COOK INLET VICINITY MAP UNIT UNIT · LONE CREEK PROPOSED · LONE CREEK N. COOK IN UNIT BAY UNIT TRADING BAY UNIT WELL LOCATION LONE CREEK d2 KENAI PENINSULA BOROUGH STATE OF ALASKA SUPERIOR CHUI~T ~ PAN AM CHU~TNA PV t APC ~ONECPEEK~ PROPOSED LONE CREE~ #2 $IMPC~ MOO 2 MOBIL MOO 2 SCALE: 1" = 5280' LOCATION PLAT APC PROPOSED LONE CREEK #2 MOQUAWKIE PROSPECT 1956~ FNL & 199~ FWL SECTION 30, T 12 N, R 11 W KENAI PENINSULA BOROUGH LONE CREEK #2 MOQUAWKIE PROSPECT DISPOSAL OF DRIIJLING WASTE BELOW 7" CASING The following information is provided to request authorization for disposal of the drilling waste through injection below 7" easing in the Lone Creek #2 well in accordance with AOGCC Regulations in Title 20, Chapter 25, 20 AAC 25.080. Well to receive drilling waste: Lone Creek #2 (below 7" casing to be set at a minimum depth of 3000'.) 2) Depth to base of potable freshwater aquifers: Estimated ~ 168' RKB (base of the quartemary/top of the Beluga). Depth to base of usable quality water aquifers: Estimated at the top of the "C" marker ~ 2093' RKB (see attached letter from Mike Globe - APC's petrophysicist).. a) Receiving Zone: Middle Tyonek sandstones, below 7" shoe at a minimum depth of 3000' to TD of well estimated to be at 6000' (3000' maximum in thickness). b) Confining Zone: Shales and Coals in the Middle Tyonek from 3000' (minimum) to 2093' (907' minimum in thickness). c) Zones to be separated by +/- 907' of formation and 1 string of properly cemented casing. Overburden pressure between these intervals is calculated at a minimum of 2308 psi. Fracture gradient at the 7" casing seat is anticipated to be 14.8 ppg MWE (0.77 psi/it) in a shaly interval. The receiving zone sand fracture gradient is anticipated to be slightly less than 14.0 ppg MWE (0.728 psi/fi). Therefore, during injection the sands should preferentially take the slurried cuttings and associated drill fluids. d) Total depth of the well is estimated to be 5000 - 6000'. This will confine the zone on the bottom side. There are no publicly recorded water wells within ~A mile of this location, nor any publicly recorded water wells within 1 mile of this location. However, Dennis Torrey (the only resident within several miles) may have a water well 7500' north east of this location. 4) The estimated maximum volume and maximum density is less than 35,000 barrels and 12.5 ppg. This volume is approximately 5 times the actual anticipated volume and reflects the possibility of a requirement to inject a substantial mount of rain water. The average slurry density is anticipated to be approximately 11.0 ppg MWE. 5) Drilling wastes are the drill cuttings from the hole, drilling fluids and associated rheologic modifiers, minor mounts of excess cementing materials, rain and wash water, and other as allowed under (h)(3) of AOGCC Chapter 25, Regulation 20 AAC 25.080. 6) Maximum anticipated injection pressure against 7" casing below injection packer to be set near shoe of 7" casing: Fracture Pressure + Friction Pressure Losses - Hydrostatic Pressure (3000') (14.8 ppg) (.052 psi/R-ppg) + 100 psi - (3000') (8.34 ppg) (.052 psi/R-ppg) 108 psi This calculation is for the worst case (highest pressure): the average injection interval depth to be 3000', maximum friction pressure losses to be 100 psi, and fresh water is the least dense fluid to be injected. Minimum anticipated injection pressure against 7" casing below injection packer: = Fracture Pressure + Friction Pressure Losses - Hydrostatic Pressure + Hydrostatic Pressure from higher fluid density inside casing. = (3000') (14.8 ppg) (.052 psi/fi-ppg) + 100 psi - (3000') (12.5 ppg) (.052 psi/fi-pg) + 3000 (12.5 - 8.34) X .052 = 2309 + 100 - 1950 + 649 = 1108 psi This calculation assumes: the average injection interval depth to be 3000', average friction pressure losses are 100 psi, and 12.5 ppg is the expected fluid density to be injected. 7) The 7" casing cement volume is calculated on bringing cement to the shoe of the 9-5/8" casing to be set at 1000'. 8) Casing Safety Factors during Injection below 7". Injection of fluids will be down 4" drill pipe with a packer set at the shoe of the 7" casing. Maximum Anticipated Casing Pressure = 1108 psi at bottom of 7" casing for injection below a packer. 7" Burst Pressure Rating = 7240 psi (70% = 5068 psi) Therefore, 9 5/8" burst safety factors for annular injection: SF in Burst = 7240/1108 = 6.53 Collapse Calculation - Injection down 7" casing so no casing string is subjected to collapse pressure. NOTE: A signed approval letter from the Tyonek Native Corporation is attached. , ANADARKO PETROLEUM CORPORATION 17001 NORTHCHASE DRIVE · P.O. B~X 1330 TEL. 1713) 875-1101 · HOUSTON. TEXAS 77251-1330 March 31, 1998 / nadaH Mr. Bart Garber Chief Executive Officer Tyonek Native Corporation 1689 "C" Street, Suite 219 Anchorage, AK 99501 Moquawkie Prospect Lone Creek Well No. 1 (Sec. 18 and 30, T12N, R11W) Annular Injection of Drilling Fluids and Cuttings Dear Mr. Garber: Anadarko Petroleum Corporation (APC) is planning, if possible, for annular injection of the drilling fluids and cuttings on the referenced wells. An application will be filed shortly with the Alaska Oil and Gas Conservation Commission at which time you will be forwarded a copy of the complete application package. We hereby request your consent for APC to inject the drilling fluids and cuttings in order for us to complete our permit application. If you agree to the foregoing, please sign in the space provided below and return one copy for our files. If you have any questions, please call either Alan Stubblefield at 281/874-8761 or Susan Hathcock at 281/874-8758. Sincerely, " bt- '~'"x Craig Lewis CL:sh AGREED TO THIS day of /'~~cl ,'/ TYONE ,K~/TIVE. CORPO,;TION By: LiJU'U Alaska 0ii & Gas Cms. ,1998 ANADARKO PETROLEUm CORPO~ iON 17001 NORThCHaSE DRIVE 1330 TEL. (281) 875-1101 · HOUSTON, TEXAS 77251-1330 / nadaH July 10, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill ( Form 10-401) Lone Creek #2 Please find enclosed Anadarko Petroleum Corporation's application for a Permit to Drill the Lone Creek #2 exploration well from the Moquawkie prospect located on the west side of the Cook Inlet. The application includes a request for disposal of drilling waste below 7" casing. Spud date is dependent on rig availability (Inlet Drilling Rig CC # 1), but may be as early as September 1, 2000. Traditional application attachments are included, as well as a Drilling Well Plan Summary sheet, which includes the majority of the data required for the application. Check No. 252964 in the amount of $100.00 is attached to cover the filing fee. This is a vertical exploration well located 1956' FNL and 199' FWL of Sec 30, T12N, Rl lW. A spacing exception has also been submitted in accordance with AOGCC Regulations 20 AAC 25.055 for both oil and gas exploration. If there are any questions, please contact me at 1-281-874-8758. Sincerely, Susan Hathcock Coordinator, Regulatory Affairs and Safety SH:me Enclosures STATE OF ALASKA AND GAS CONSERVATION coM' PERMIT TO DRILL ALASKA 20 AAC 25.005 SSION - , la. Type ct work Oritl ~2] Redrill ~j lb. Type of well. Exploratory [] Stratigraphic Test ~ Development Oil ~ Re-Entry r-'J, Oeeoen Semice ~m Develooement Gas [] Single Zone m~ Multiple Zone ~ 2. Name ot Ooera[or 5. Datum Elevation (DF or'K~) 10. Field an~ ~oi ~a~ko Pe~ole~ ~ration 443 ~ feet Wildcat 3. A~aress 17001 ~~ase Drive 6. Prope~y Designation Houston, ~ 77060 C061388 , 4. ~cation of well at Surface 7. Unit or prope~y Name 11. Type Bond(,,,aA~2s.o~) 1956' ~ & 199' ~,S~. 30 T12N,RllW ~ne ~ BlUet At [o~ of ~ro~uctive info,al '8. Well nu~er " Number ~8726 1956' ~ & 199' ~,S~. 30 T12N,RllW ~2 At total depth 9. Approximate s~ud date Amount $200,000 1956' ~ & 199' ~,S~. 30 T12N,RllW 9-5-00 12. ~is~ance [o neares~ " 13. Distance to ~earest well ~4. NumDer o~ acres in propert~ 15. Proposed ~epth(,o,,~ wo~ property line . 199 feet 8100 feet~ 2924 6,000 ~/~ feet ~6. To ~e completed for deviated wells ~ 17. Anticipated' oressure (~, :o**c :5.o35 (,,z~) Kickoff de¢tn n/a feet n/a Maximum hole angle "[,"'.'~.~ ,~,... 2297 ~,,.., ,0,., ~.o,. ~o~ 2602 ,"'. ~8. Casing program' ~ Setting. Death j ... size Soemficafions ~ ToO ~o~tom} Quantity of cement Hole'~ Casing Weignt'"~ra,e'Cou~lingj~ngtn ~ ' MO ~D , MO, '~O '" (include stage,ara) ~rive ,20" ?2ppf '~_'56 ' ~d 751S~f' ~f.~7~" 75¢ ~=iv~ ~. ft. ,. 200 ~. ,s~f. 206 , 200l 300 ~._. ft. 17-1/2~ 13-3/8:,t68ppf 80'" , 12-1/4~ 9-5'/8 4~Ff (~=55' ~ 10001~f. S~f.. 100C" 1000[ ..... 600 ~..'ft, 8-1/2f ?" 26PPf ~18'9'- B~ t 5000~ ~f IS~rf 5006 50001 80~ ~, ft. 6" j 5" 18ppf ~-80 ~ I 1200t 4800 14800 600d 60001 200 ~. ft. 19. To ~e completed for Redrill, Re-entu, and O~epen Operations. ' ...... Present well condition summa~ Total dept~: measured feet Plugs (measure~) true vertical feet Effective dept~: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured de~th True Vertical depth Structural , . Conductor Inlermediate Production 0 R I GI NA L ,,000 Liner t~,~ Perforation depth: measured ~Oi~ ~ GssC~'$.~I~} true vertical A~ch0f~e 20. Attacnmen'is' Filing '~ee ~ ProPerty p~a[~ 8~P"Ske{ch~ Oiverter Sketch~ Drilling program ~ ' Drilling fluid program ~ Time vs deot~ plot ~ Refraction analysis Q Seabed report Q 20 AAC 25.050 requirements ~ , ,,, , , 21. 'i hereby certify that the foregoing i~ true ana correct to [he best ot"~y knowledge _ S,qS~~~. To~. ~o~sonTRle'Division Drill~9 ~~t~d~at~_13_00 ~ ~ Commission Use Only ~_/~ ~~ ~.~ 'Approval da[~' _~ Se; cover letter ..... -- -- ?~/ ~ ~ for other requirements Conditions of approval samples required ~ Yes ~ No Mud Icg required ~ Yes G No Hydrogen sulfide measures ~ Yes ~ No Directional su~ey required G Yes ~ No ~m~¢~ ~,-¢~ Required working pressure for DOPE G2M; ~3M; ~ SM; ~ 10M; ~ 15M ~¢~. Other: by order of Approved by ORIGINAL SIGNED BY Commissioner the commission Date ~ ~ J ~ ~ ~ ~ , , , Form 10-401 Rev. 12-1-85 D Taylor Seamount Sunm~t in triplicate TO: FROM: SUBJECT: Petroleum Corporation Inter-Office Correspondence P. Leach/T. Thompson M. P. Globe /~". /~..,~ ~ Formation water salinities on the Moquawkie Anticline July 11, 2000 Attached are "Rwa" analyses on two wells on the Moquawkie Anticline, the Simpco E. Moquawkie #1, and the Lone Creek #1 st1. Rwa is a technique that calculates apparent formation water resistivity from computed log porosity and measured formation resistivity. In the case where formations are fully water saturated, Rwa is a close approximation of true formation resistivity, and thus salinity. In hydrocarbon bearing zones, the Rwa technique will yield an apparent formation water resistivity that is higher than true formation water resistivity. The attached plots include computed shale volume, sp, Rwa, and resistivity curves. Rwa has been calculated in the sands only. Also included on the plots is a curve labeled "LIM". This curve denotes the resistivity equivalent of a 3000 ppm NaCI brine versus depth. The resistivity equivalent value decreases with depth due to increasing formation temperature. Resistivity is inversely proportional to salinity, so a decreasing Rwa value corresponds to an increase in salinity. In those places where the Rwa curve is to the left of the LIM curve, the zones have formation water salinities in excess of 3000 ppm NaCI equivalent. It is evident from these two logs, that from the top of the "C Marker" stratigraphic section doWn, all water-saturated sands have formation water salinities well in excess of 3000 ppm NaCI. Those sands within these sections that exhibit Rwa values above the 3000 ppm line are fully or partially gas saturated. Please contact me with any questions or comments. Simpco E. Moquawkie #1 RMF RMFT BHT 3,000 PPM £qulvalent .1 LIM 10 -!~0 SBL 21} MV ,Salinity > 3,1:K~ .2 I LD 2000 0 VSH I RWA~ LIM OHMM 1:450,0 FRAC .1 . .. RWA 10 FEET .2 SFLIJ 2000 ..... ~'"-'~ ......... ~ ......... ~ ......... .50 MD OHMM VSH ':':':":':'"':'"*; ............. ; ............. ~ .... iii!iii!: : : :::::: : : ::::::- -::::::: "--:::::: ::!::::: iiii!!!i! · i iiiiii · i iiiiii_ 4100_ .::::::-,;,.~~,.,,. ............ ,,,,.,., ........ I i i i i i i i i i i i i i i i i iiiiiii i i i i i iiiii ............ _ ........... ::::: ,, ,:::.~ ~ .......... ::::: el _. iI : ~_ i. _l : _·'~i~ ~ · I , ; i"i i~ · i i I i i i , -- i lllll I I I IIllI . !-TT . ;; ;;;;; ,ooo .......... : :::::: i i i iii;i 4400 ~','.',', ....... , : : :::: 4600 ..... i~., ...... : ! ! !!!!!- - ......... ! ;: ;:;:;:ii;,' : !! !!!!! 47o0 : : :::::. : i iii!i! 4aoo ..::::: ~ ~ " ..... . : : :::::_-- -- ::::::: ....... i:iiiii!iii '~~ .~ : :: :::::sooo ::',',:',: '""'i.~ !::::::: ........ iiiiiiiiii. , .~ : : :::::' · : ::::::-- - '~,*":::::::: .......... "' : : : :::: ' '. '. ::::: ..~L:q)O '.:::::: '. .... ~ --. ....... iiiiiii!i -- : :'":~:::'~ ?: ::::: ~.'.'~o ::'.:' · ..... ........ : ; :;:;:_ _ ;:;:::: ,,,:;:::Y.._~_ ............... , ~ ....... . ....... ,,::::: :: .... ,._~.~ :;~ --'::::: it' ~ I , ........ :: :-,~. ~4oo ::::::: ' ~/. . '-: ..... ",'"'"'" .... ~ · . ...... : : :::;::s~oo ................,..~;;. :::;:::: <1: · -': ~-P.1: ::::~=:==.~ ........ -- ,5800 ..... i~ ~'"~' .................. : : ':- .... ~ : :::::::- s~0 '"~ ..... ~.."t':..~..:-:.:."~ ~ ; , , ,,,,, , , , ,.,,-, i . i · i . i I i i · i i i i i11s11 !:i'!!"iii!' ' : : ::::;, : : ;;:::: 6000 '"::::: ":ii~ i ::::: ' i~' : ! ! ! !!!~ ........61oo ..::::: ........ ~ ............... : ::::::6~oo_ !!!!!!! !!!~._~,._. ........ .. . ' ..... ------------- r=~oo :'-:::'-"' "~ ~"~ ~,i ii iiiii '- ~''-::'' .... I : : : ::::: 15400 , , ...,: ...... · ........................ i~oC]10 : 1::1:1 : ;; ........ ,:;:,, . ,,,,:,,:: ......... -.~..=::~...:.~..: :,:.;,; : , ~~: ' : ::::::__ __ ,,::::: ~L____~i ..... ' ' :::::', !!!!iii!: "<-v-'.~ . , .~., .... ,_t! ........ 67oo .................... L uNE CREEK #1 ST1 3,000 PPM Equivalent .1 LIM 10 ,, .2 AFgO 2000 0 VSH I OHMM FRAC Salinity > 3,000 .2 AF60 2000 VSH ':::"' '"'""':' .:"-F ''! ":~'..' :.'::...,..:...:.......-:....., ,50 RWA~ LIM OHMM 1:4500 -SD SI3 2,1) ,1__ RWA 10 FEET :.2_ ............. .A..F..2.O. ......... _2..0..O.0.. ~ MV OHMM MD OHMM ~ .: ..... . .... ~: :: :::::?~'..'",.:iii ~ H.:-...:-:->: .... ,~.~.~;::,~', ......... , ' · o .... ---~='?':':~~; ; i .... ; ~-~';:::'~'~'-"" ; ; ;;; ;;; 2:200 ..... ,;~ =..,.~; ;;;;; - --;;;;; ', ..~.,...:~..:..:~ ,, ,, ! .......... ~.%.'., _,...:,,, ; : ,, ,,: ,,: :', - . ::::::............ :. :::::: a ii~ll~j~l.e~........~ i , , I · , , I , I i I i · i · I , -- -- Illl I lille[ ~:.:!:i~!:!::..':!:!':"".'.'.'.'.'.'.'.~ '. : : : '.:: :: '. ~::: ::: -- -- :::'. : '. :::'.:: ~,,~ ........ -~:----'.~.~:.:+.~.:.'-"-:.~.:.:..~'~ : : .............. :::"~ : ::: :::: 2soo ...i: ...... " = ........ : :!.!!!ii ........ : :: :."::: ........ ..... ~ ........ - 2600 ...:::: i i :~ -'~=~::::" ........ _ , __- ~ ' : : :::;: : : : :::::-- -- · .......... ~- ................. 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','.~', 3500 ................. ~ c., I I I ~ -- ii I I -- I , ............... '~ ':---~ i :_.;~;:?.~ ' : : :::::- - ':::::: , ,:~~:: .~, .._: : :'::::: :~i i- ~:':':':':':"":" : : : :, i ~ . : : ::;:: 3600 .--:::: :::~ ........ ~:~.~~~:!:...,~. '. ' :: :...¥= : ::: :::: ..... :::: : :_~':,ii'~,~:::: ........ "~'..... i i i iii: 3700 ~::;;~:;::.':;!;~::;::::::i;~ : : : .... ....... 3eeo ....... :~ . . ~.-:::~"-'".:i-:::-~, : ', ' :: :: ' : :: :::""- - '""::: :~_:i": ' -' .... '~ ' : : ::::'. 3900 '"'Y.: , :.',-:.'; ........ : , ~ , 4000 ....... ,..-,-, ............... ......... -- __ , ...... ~ .'.... ::',::: : ~,.,._,:,.: ,, , ~~ : ::: :::: ..... :::: : ' , ,,',:::: ...~ :.... ==,.. _'--~ ' ', ', :: :~', 4200 ............ ~__,.~.,,~.,._,,.._ "-: : : :::::: : : ::::::- -::::::: ........ ~ '"::::i - ' ' ....... 4400 '":::: , . ' ........ iii~! : ~: ' '~: : ::::: , : : Z:::: 4~;oo ......... i~. :!::~ :' ii'" i ................ - I ........... """:""":- ::" ...... " , ,.....- : :::::::_ ........ .......... i : :::::::- ' !iiiii;: ;:i' .- ........ ....... : ~~.,"-::::::~ : : ::::: 49~30 ........... ~ : ::::::: '"::::: adaH(p Lone Creek Well tt2 Drilling Action Plan 1NLET DRILLING RIG-CC #1 Last Casing/Hole Size/ Next Casing 20" ~ 75' 12-1/4" Pilot Hole to 200' 17-1/2" hole/to 200' 13-3/8" ~ 200' and 12-1/4" hole/to 1000' 9-5/8" ~ 1000' 8-1/2" hole to 5000' 7"@ 5o0o' 6" hole to 6000' Potential Problems Shallow Gas Hole pack off (unconsolidated formations) Loss of circulation (Part/al/Total) Preventive Action Minimize swab pressures. Circulate bottoms up after drilling break. Check for flow at each connection. Perform false connections. Drill with appropriate mud weights. Closely monitor background gas, connection gas, short trip gas, trip gas and hole fillup on trips. Use relatively high viscosity & yield point mud. Maximize flow rate, Control drilling (ROP), Extra circulation. Circulate hole clean before POOH, Circulate sweeps. Maintain minimum safe mud weights, maximize hole cleaning, control drilling (ROP), minimize surge pressures, pretreat mud with LCM, Warning Siuns High gas content in mud, increases in background gas, connection gas, short trip gas, and trip gas, gas bubbles, increased circulation rate with reduced circulation pressure, decreased mud density, increased pit volume, hole doesn't take enough mud while POOH. High pump pressure with decreasing gpm. Increased torque and drag, fill on connections, decrease in mount of cuttings without ROP change, over pull off of slips, swabbing. Pit volume loss, loss of returns, excessive hole fill up, loss of circulation pressure, prognosed loss zones (gravel), poor hole First Action to Warning Stop drilling/tripping, check for flow, report to supervisor, trip back to bottom, circulate hole clean, possibly increase mud weight, and/or increase circulation rate. Stop drilling, continue circulation and pipe movement (if possible) report to supervisor. Increase circulation time & mud theology, keep pipe moving. Circulate hole clean. Stop drilling, keep string moving. Fill annulus with fresh water, keep hole full. Report to supervisor. Reduce pump speed to ½. Safet.v Issues Stop all hot work, paint chipping, etc. Potential well control event. With diverter installed, implement precautions per AAOGCC .20ACC 25.035 (C) (3). Be prepared to stop pumps with potential sudden total pack off. Stay clear of pop off valves and vent line plumbing. Potential loss of circulation & stuck pipe Potential well control event, stuck pipe. Stuck Pipe (due to hole pack off) monitor fluid levels, use minimum mud theology to keep hole clan, jet bits to allow for LCM pills. Rotate string before starting pumps. Minimize potential for hole pack off and lost circulation, as above, slow tripping speed and minimize circulation time when BI-IA is opposite unconsolidated formation. cleaning, hole pack off. Increased torque, drag and or pump pressure, fill on connections, bridges on trips, reduced circulation and cuttings without ROP chan~e, shale cavin~s. Spot LCM pill. Monitor fluid levels/loss rates. Allow hole to heal. Minimize mud rheology. Report to supervisor. Prepare to jar. Stand clear of floor with high over pull and jarring. Keep derrick man out of derrick. Last Casing/Hole Size/ Next Casing Potential Problems Stuck Pipe (coal stringers) Wellbore Geometry (micro dog leg and ledges) Wellbore Geometry (Tectonic Stress) Differential Sticking Preventive Action Only drill 2' of drilling break, back ream and circulate, use appropriate mud additives, minimize swab and surge pressures, control drill (ROP). Use appropriate BHA's, wiper trips, ream/back ream tight sections, minimize direction/angle changes, slow trip speed before BHA enters suspect zone. Maintain mud theology to ensure hole cleaning, use sweeps to help hole cleaning, minimize surge and swab pressures, ream and back ream tight sections, potentially increase mud weight. Use minimum safe mud weight required for hole stability and well control, maintain low fluid loss, minimize BHA length, use spiral drill collars, deep BHA moving (minimize open hole static time for surveys, minor repairs, etc.) Warning Signs High ROP increase. Increased torque and drag, increased pump pressure & decreased gpm, bridges on trips, fill on connections. Erratic torque and drag, deviation changes and ROP, prognosed hard/soft interbedded formations, generally occurs while tripping/making connections, circulation is unrestricted. Repeated tight spots at same depth on trips. Prognosed tectonics, erratic torque and drag, blocky shale cavings, restricted circulation with increased cuttings without increase in ROP, overpull off of slips, swabbing. Increased drag, over pull off of slips, increased torque to start string movement. First Action to Warning Stop drilling, pick up and back ream. Circulate clean. Report to supervisor, prepare to jar on pipe and spot pipe lax across bit/BHA. If possible, maintain string movement, continue circulation. Notify supervisor. Ream and back ream. Circulate hole clean. Prepare to jar on pipe ff stuck. Continue pipe movement and circulation (ff possible). Notify supervisor. Ream and back ream tight spots. Potentially increase mud weight. Notify supervisor. If stuck, apply torque and jar down with maximum trip load, spot pipe releasing pill. Safety Issues Stand clear of floor with high over pull and jarring. Keep derrick man out of derrick. Stand clear of floor with high over pull and jarring. Keep derrick man out of derrick. Stand clear of floor with high over pull and jarring. Keep derrick man out of derrick. Stand clear of floor with high over pull and jarring. Keep derrick man out of derrick. Pa[~e 2 Inlet Drilling Rig - CC # 1 Diverter Schematic ! I 13-5/8" 5000# Annular Preventer 13-5/8" 5000# Flanges 10" 150# HCR Knife Gate Valve (Auto open on annular closure) 13-3/8" Conductor Pipe Note: Diverter Outlet to terminate at least 75' 'from any ignition source A request for a variance to use a 10" rather than 12¼" vent line (hole size being drilled below diverter is 12¼") was filed with the AOGCC on July 13, 2000. LONE CREEK #2 BLOWOUT PREVENTION EQUIP NT 13-5/8" Diverter 1 ea 13-5/8" x 5000 psi wp annular preventer 1 ea 13-5/8" x 2000 psi diverter spool w/10" outlet and 150 psi knife valve (knife valve automatically opens when annular shuts) 1 ea 10" diverter line 13-5/8" BOP Equipment 2 ea 13-5/8" x 5000 psi wp ram type preventers 1 ea 13-5/8" x 5000 psi wp annular preventer 2 ea 4-1/16" 5000 psi side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea BOP accumulator, Koomey, 3000 psi w/(12) 10 gallon bottles, 180 gallons, and (1) 120 gallon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, ak pump Model G7E. 8 bottles nitrogen backup. 1 ea Koomey, 5 station, remote control panel 1 ea Thornhill Craver, automatic choke 3"- 5,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. Inlet Drilling Rig - CC #1 .o psi BOP Stack 51e'51~I Read' 3-- 1 f8' Kill Line~ I r. HCR. Valw 2-- (~ate Valve 2 I 3-118" Choke Line LONE CREEK #2 DRILLING FLUID SYSTEM DESCRIPTION INLET DRILLING RIG- CC#1 Mud Pumps 1 ea Gardner Denver PZ-9 7" x 9", 1000 HP with (1) K-20 pulsation dampeners, powered by a 398 TA Cat engine. 1 ea. 214P Oilwell powered by Twin 671 Detroit diesel engines. Mud Tank System (500 bbis Active Volume) Tank #1 (shaker tank) appx. 143 bbls. Three compartmems which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 143 bbls. One compartment equipped with desander, desirer, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 143 bbls. Three compartmems, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Current Mud System Equipment 1 ea 1 ea 1 ea 3 ea Brandt dual tandem shale shaker Tri-Flo-degasser Pioneer Model S-800 sidewinder mud hopper Medearis revolving guns 250' Access Road Overburden Storage Area 50' X 50' Flare Pit Lined Reserve Pit 100' X 100' Sump , , Choke Manifold Mud Mud Pits/Solids Pumps Control & Package Power Units Misc Storage 000 Central Rig Pkg ~ 2' Berm I - No fences, access ramps, surface water and erosion control devices are anticipated to be required. 2 - Any and all fluids that are collected on location will be transferred to the monofill via a sump pump. 3 - Test tanks will be located on the bermed well pad in or around the pipe rack area and possibly in other areas not occupied by existing equipment. I MOQUAWKIE PROSPECT LONE CREEK #2, LOCATION LAYOUT KENAI PENINSULA BOROUGH S:V~,laska\Drilling\Lone Creek 2\location layout LC 2 ~ STATE OF ALASKA _ ANADarko PETROLEUM CORPORA!..~n 17001 NORTHCHASE DRIVE · P.O. B~. .330 TEL. 1281! 875-1101 · HOUSTON. TEXAS 77251-1330 July 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Mr. Blair E. Wondzell, P.E. Application for Oil and Gas Exploration Spacing Exception Lone Creek//2 (Sec. 30, T12N, RllW) Dear Mr. Wondzell: Anadarko Petroleum Corporation (Anadarko) requests a spacing exception in accordance with the requirements in 20 ACC 25.055 for its planned Lone Creek #2 exploration well in the Moquawkie prospect located on the west side of the Cook Inlet. This is a vertical well' located at 1956 FNL and 199 FWL of Sec. 30, T12N, RllW. It is within 500' ora quarter section line for a potential oil discovery and 1500' of a section line for a potential gas discovery. Enclosed is a surface location plat for this well and any known wells in the immediate area. Anadarko operates the leases on the adjacent and diagonal quarter and section drilling units and are equal partners in all units with Phillips Alaska, Inc. As such, no registered notification is necessary. I am acquainted with the above facts and verify that those facts are tree and that the plat correctly portrays pertinent and required data for this request. If there are any questions, please contact either Tommy Thompson at 1-281-874-3262 or myself at 1-281-874-8758. Sincerely, Susan Hathcock Coordinator, Regulatory Affairs and Safety TT:nl Enclosures (1) 2~-19 S 88°~I'58'' E 4993.86' 25 ,,~__N 2599638.13 E 268416.33 N 2599539.30 E 273406.21 ROAD ~198.83' LONE CREEK ALT. PAD #2 N 2597684-.00 E 268579.00 PROPOSED :ULVERT SEC. 30 SCALE 1" = 1000' 3O N 2594-359.39 E 268310.71 N 2594260.30 E 273317.91 31 N 88'51'11" W 5008.17' 120 o 0 Z 31 '32 VICINITY M AP N.T,S. R[:-CEtVED JUL i 8 2000 ~chorag,e NOTES 1. DATE OF SURVEY MAY 21, 2000. 2. REFERENCE FIELD BOOK FRB 97-04 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD27. 4. HORIZONTAL CONTROL IS BASED ON MONUMENTS CPI-ID AND CP2-1D. LEGEND ~ AS-STAKED WELL CONDUCTOR f LOCATED WITHIN PROTRACTED SEC. 56, T 12 N, R 11 W, SEWARD MERIDIAN, AK. ANADARKO ----~'~)"~", l LONE CREEK WELL #2 "Xvt ....... "f.o t, '~" ,~,''; O~., ~1 1% ?. Robert " "~ / ~ ~ F. ROBERT BELL a ASSOCIATES " T '.~It ~,~A IOlldllt ~o~ w. FIREWEED LANE ¢~". N0, 5252-S .' ~/ [FILE NAME: '1. ~¢j" ...'_ ~ ~ /sc*~: / ~M ...... t ,¢~ / ~"=~ooo' / ~ /ANADARK° '~~~ l 20002~ / ~ ~ /~ Lone Creek #2 Moquawkie Prospect Pressure Profile 0 - - estimated pore press , ___ ,proposed mud weight ' ~ ~ calculated frac grad 9-115/8" ,,, El proposed csg pts 1ltl, 8' _ Tyonek , 2~)93'-i 'C' Mark :r ! ! I ! ! ! 1 4218'- 'F' Mark,~r ! 71 ! ! ! I I I I ! ! ! ,,_ 1000 2000 3000 5000 6000 7000 8000 4000 8 9 10 11 ~12 13 14 15 16 17 18 19 Equivalent Mud Weight (ppg) S:~laska\Drilling\Lone Creek 2~pressure profile LC 2.xls presSure profile LONE CREEK #2 CASING & PRESS~ INFORMATION ,. Settin~ Depth Size Specifications Top Bottom , ,, Hole Casing Weight Grade Coupling Length MD TVD MD TVD Drive 20" 92 ppf X-56 WELD 75' Surf. Surf. 7~ 75' i7 1/Z' 13 3/8' 68 ppf L-80 BTC 200' Surf. Surf. 200' 200' 12 1/4" 9 5/8" 40 ppf K-55 BTC 1000' Surf. Surf. 1000' 1000' 8 %" 7" 26 ppf L-80 BTC 5000' Surf. Surf. 5000' 5000' 6' 5" 18 ppf L-80 SLX 1200' 4800' 4800' 6000' 6000' ., Casing Joint Strength Body Strength Burst Collapse ~ ~s ~ ~s ~,s~ ~,s~ ~3 3/8" 68~ L-80 BTC 1545 1556 5020 2260 9 5/8" 40~ K-55 BTC 486 630 3950 2570 7" 26~ L-80 BTC 641 604 ?240 5410 ~5" 18~ L-80 SLX 351 422 10,140 10,500 Casing Specifications from USS Seamless Oil Coumry Tubular Products Publication and Hydril Tubular Products Publication. Lone Creek tt2 Casing & Pressure Calculations Conductor Casing Casine Soecifications: Conductor Casing Set from GL to 200' MD, TVD Collapse Rating = 2,260 psi Burst Rating = 5,020 psi Joint Strength = 1,545,000 lbs Body Strength = 1,556,000 lbs Collapse Design = 100% 13.375" 68 ppf, L-80, BT&C Maximum Anticipated Surface Pressure below Conductor Casing: 13.375" 68 ppf, L-80, BT&C set at 200' TVD 12.250 inch hole drilled to 1,000' TVD Fracture Gradient at Surface Shoe = 11.0 ppg EMW Mud Weight at next Casing Point = 10.0 ppg Fracture Pressure at Shoe (PO = 11.0 x 0.052 x Gas Gradient = 200' x 0.04 psi/fi MASP = 114 - 200' 114 psi 8 psi 106 psi Casin~ Test Pressure: Test diverter to 110 psi Note: diverter to be rigged up on this casing string Casinl~ Design & Safety Factor Calculations: NOTE: Conductor casing will be landed and cemented to surface to supplement stability and collapse design. Collapse Design = ( Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 200' x 100% 10.0 x 0.052 ) = 104 2,260 psi / 104 psi = 21.73 Burst rating / MASP (or test presSUre, which ever is greater) 5,020 psi / 110 = 45.64 Lessor of joint or body strength / running load 1,545,000 lbs / 68.0 lbs/ff x 200' x psi 0.85 = 132.91 DESIGN FACTORS' Collapse Burst Tension 21.73 45.64 132.91 C:~=XCEL~DRLGPLAN~PD Calc LC 2.xls - 7/13/00 Lone Creek//2 Casing & Pressure Calculations Surface Casing Casing Soecifications: Surface Casing Set from RKB to Collapse Rating = Burst Rating = Joint Strength = Body Strength = Collapse Design = 1,000' MD, TVD 2,570 psi 3,950 psi 486,000 lbs 630,000 lbs 100% evacuation 9.625" 40 ppf, K-55, BT&C 70% = 2765 psi) Maximum Anticipated Surface Pressure below Surface Casing: 9.625" 40 ppf, K-55, BT&C set at 8.500 inch hole drilled to Fracture Gradient at Surface Shoe Mud Weight at next Casing Point Fracture Pressure at Shoe (PO Gas Gradient MAS? 1,000' 5,000' TVD TVD = 12.5 ppg EMW = 11.0 ppg = 12.5 x 0.052 x = 1,000' x 0.04 psi/fi = 650 - 1,000' 40 = 650 psi = 40 psi = 610 psi Casing Test Pressure: 1,500 psi for 30 min. prior to drilling out of the casing shoe Casing Design Safety F, actor Calculations: NOTE: Surface casing cememed to surface to supplement stability and collapse design. CollapSe Design = Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 1,000' x 100% x 10.00 x 0.052 = 2,570 psi / 520 psi = 4.94 Burst rating / MASP (or test pressure, which ever is greater) 3,950 psi / 1,500 psi = 2.63 Lessor ofjoim strength or pipe body / running load 486,000 lbs / 40.0 Ibs/fi x 1,000' x 0.84 520 psi = 14.46 DESIGN FACTORS Collaose 4.94 Burst 2.63 Tension 14.46 S:V~laska\Ddlling\Lone Creek 2~PD Calc LC 2.xls Surf Lone Creek #2 ( Casing & Pressure Calculations First Inter./Prod. Casing Casing Specifications: First Inter./Prod. Casing 7" 26 ppf, L-80, BT&C Set from RKB to Collapse Rating = Burst Rating = Joint Slxength = Body S~ength = Collapse Design = 5,000' TVD, 5,410 psi 7,240 psi 641,000 lbs 604,000 lbs 50% evacuation 5,000' MD (@ 70% = 5068 psi) Maximum Anticipated Surface Pressure below First Intermediate Casing: 7" 26 ppf, L-80, BT&C set at 5,000' TVD 6.000 inch hole drilled to 6000' TVD, then set 5" production liner at Fracture Gradient at 5,000' = 15.8 ppg EMW Mud Weight at Proposed Total Depth = 11.0 ppg Pore Pressure 'at prospective production depth (Pp) = 8.34 x 0.052 x Fracture Pressure at Shoe (Pf) = 15.8 x 0.052 x 6OO0 5,000' 6000' TVD 2,602 4,108 psi psi From the Weymouth Equation which calculates MASP in production mode: s?c s) ,- ?p 1 e .0000347 GZp = 2,602 1 _x,,x e .0000347 x.6 x 6; = 2,297 psi Or from the modified Weymouth Equation with loss of circulation during a kick the MASP is calculated as follows: MASP (Ps) = Pf ~ 1 ~, X ~40000oF,/,,'" e .00oo34? ~zp Zp = 4,108 1 _X,,. X 4000 e .oo0o347 x.6 x 5, 5,000' = 3,311 psi (pore pressure ~ 6,000' can only generate 2297 psi ~ surface) Casing Test Pressure: 3,000 psi for a 30 minute period prior to drilling out of the casing shoe Casing Design Safe .ty Factor Calculations: Collapse Design = Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 5,000' x 50% x 11.0 5,410 psi / 1,430 psi = 3.78 Burstrating/MASP(ormstpressure, whicheverisgreater) 7,240 psi / 3,000 psi = 2.41 Lessorofjointstrengthorpipebody/ruaningload 604,000lbs / 26.0 lbs/R x 5,000' x 0.052 = 1,430 psi x 0.83 = 5.59 DESIGN FACTORS CoHap,se 3.78 Burst 2.41 Tension 5.59 S:~Alaska~Drilling~one Creek 2V~PD Calc LC 2 1st Inter Lone Creek tt2 Casing & Pressure Calculations Production Liner Casine Specifications: Production Liner 5" 18 ppf, L-80, SLX Set from 4,800' TVD, MD to Collapse Rating = 10,500 psi Burst Rating = 10,140 psi (~ 70% = Joint Strength = 351,000 lbs Body Strength = 422,000 lbs Collapse Design = 50% evacuation 6,000' 7098 TVD, MD psi) Maximum Anticipated Surface Pressure below Casing: 5" 18 ppf, L-80, SLX set from 4,800' TVD, MD to Mud Weight at Total Depth = 11.0 ppg Fracture Pressure at 7" Shoe (Pf) = 5,000' x 0.052 x Pore Pressure At. TD (Pp) = 6,000' x 0.052 x 8.34 6,000' TVD, MD 15.8 ppg= 4,108 psi ppg - 2602 psi From the Weymouth Equation which calculates MASP in production mode: MAS? (Ps) = Pp = 2,602 e .0000347 Gzp e .0000347,0.6 6, = 2,297 psi Top Of Liner Casing Test Pressure: TOL Test Pressure = Fracture Pressure at the 7" Shoe + 500 psi minus hydrostatic pressure due to mud = ( 4,108 psi + 500 psi ) - ( 11.0 ppg x .052 x 5,000' ) = 1,748 psi TOL Casing Test Pressure: 3,000 psi with an 11.0 ppg mud hydostatic for a 30 minute period Casin8 Desien Safety Factor Calculations: Collapse Design = Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 6,000' x 50% x 11.0 x 0.052 = 10,500 psi / 1,716 psi -- 6.12 Burst rating / MASP (or test pressure, which ever is greater) 10,140 psi / 3,000 psi = 3.38 Lessor of joint strength or pipe body / running load 351,000 lbs / 18.0 lbrdft x 1,200' x 0.83 DESIGN FACTORS Collapse Burst Tension 6.12 3.38 19.54 1,716 psi = 19.54 C:~=XCEL~DRLGPLAN~PD Calc L,C 2 7/10/00 LONE CREEK #2 CEMENTING PROGRAM Conductor Casing WELL DATA DEPTH 200' MD / TVD HOLE SIZE 17 1/2" PIPE SIZE 13 3/8" OD, 68 ppf MINIMUM VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives Surface Casing WELL DATA DEPTH 1000 'MD / TVD HOLE SIZE 12 IA" PIPE SIZE 9 5/8"OD, 40 ppf MINIMUM VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives Production/Intermediate casing WELL DATA DEPTH 5000'MD / TVD HOLE SIZE 8-1/2" PIPE SIZE 7"OD, 26 ppf VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives Production Liner WELL DATA DEPTH 6000' MD / TVD HOLE SIZE 6" PIPE SIZE 5"OD, 18# VOLUME REQUIRED TOTAL VOLUME TOP OF cEMENT CEMENT Slurry_: 15.8 ppg - Class G + additives 300 cf Sufficient to circ to surface Sufficient to cftc to surface 800cf ~ %'"750'h~ Sufficient to circ to 1000' 200 cf Sufficient to cftc to TOL Lone Creek #2 Moquawkie Prospect Offset / MW vs Depth 2o0o 4000 6o00 ~6ooo ~ Simpco Moquawkie #1 ~ Simpco Moquawkie #2 ..... Mobil Moquawkie #1 ~ Mobil Moquawkie #2 ~ Superior 3 Mile Creek · Simpco Moquawkie #1 RFT Data · Simpco Moquawkie #2 RFT Data III Mobil Moquawkie #1 RFT Data Simasko E Moquawkie #1 RFT Data -----APc Lone Creek #1 10000 12000 14000 16000 8 9 10 11 12 13 Mud Weight (ppg) moquawkie-nephaline offset Pressure Profile (2) 7/7/00 14 15 16 17 18 ~'~ i TEL. (2811 875-1101 ANADARKO PETROLEUM CORP .... ON ~7001NORTHCHASE DRIVE · P.O. B'~,,, 1330 ., HOUSTON. TEXAS 77~51-~330 July 13, 2000 Alaska Department of Administration Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Mr. Dan Seamount-Commissioner Re: Application for Permit to Drill Lone Creek # 2 RECEIVED, '-' JUL i 7 2000 AlaSka 0il & Gas Cons. Commission Anchorage We have on this same date filed an Application for a Permit to Drill the subject well (Forml0-401). The purpose of this letter is to request a variance for Lone Creek # 2 to use a 10" Diverter Vent Line rather than a 12 lA" Diverter Vent Line as required by 20 AAC 25.035. (See a description and layout of the proposed Diverter System in the Application to Drill Lone Creek # 2). This request is based on the following: 1) Drilling below the diverter will proceed from 13 3/8" casing setting depth proposed at 200 f~ MD/TVD to 1,000 Pr MD/TVD. (13 3/8" shoe set below the base of the Quaternary gravel and 50 Pr into the Beluga formation). 2) Examination of all seismic data in this area indicates that there are no seismic anomalies or other seismic signatures that are typically related to the presence of gas accumulations in the shallow part of this section. The study area also included the Mobil Moquawkie # 1 well referenced below. (Refer to Seismic Evaluation for Shallow Hazards letter in the Application for Permit to Drill Lone Creek # 2.) 3) There are 10 existing wells within a 3 mile radius of Lone Creek # 2 which helps to establish a data base and eliminate some uncertainty, as compared to a complete wildcat many miles from any well control. One of these wells, the Mobil Moquawkie # 1 experienced a blowout at a depth of 1525 f~ MD/TVD. This same stratigraphic interval is expected in our Lone Creek # 2 well at 1,198 Pr MD/TVD. As indicated in the Application for Permit to Drill Lone Creek # 2, we will be picking the 9 5/8" casing point to be above this interval. We could find no other incidents of shallow gas in the other 9 wells. . The well files on the Mobil Moquawkie # 1 well indicate that the well started to flow and subsequently blew out while on a trip from 1,525 ft with 10.0 ppg mud in the hole. At the time of the blowout (0315 in the morning on May 4, 1965), 90 t~ of drill collars were above the rig floor, the remaining 256 f~ of collars were below the drill floor with the bit at 256 f~). This strongly suggests that the well was swabbed in on the trip, and very late in the trip, as opposed to encountering a high pressure shallow gas zone that began to flow while drilling on bottom. Therefore, the 10.0 ppg mud in the hole was adequate while on bottom but not for tripping. We plan to drill out below 9 5/8" casing set above this zone with an 11.0 ppg mud as shown in the Application for Permit to Drill for Lone Creek # 2. There is also no indication that any well control equipment was installed on the Mobil Moquawkie # 1. Improved drilling practices currently in use, higher levels of training of drilling personnel and more sensitive detection equipment compared to 35 years ago should result in a much safer operation today. Installation of secondary well control equipment also provides additional protection. Experience gained while drilling the Lone Creek # 1 well in 1998 also makes us more aware of the potential problems in this area. 4) The hole size to be drilled below the diverter is 12 lA" which is not significantly larger than the 10" diverter vent line size being proposed herein. In view of the above, we ask that we be granted a variance to use a 10" rather than a 12 lA" diverter line on our Lone Creek # 2 well as provided for in 20 AAC 25.035, Section (h), (2). Your consideration of our proposal is appreciated. Sincerely, Tommy Thompson Drilling Superintendent CC: Mr. Blair E. Wondzell, PE ANADARKO PETROLEUM CORPORAl, 3201 C STREET, STE. 603 ANCHORA~ ~9505 U.S.A. PH. (907) $63-951~ July 11, 2000 Moquawkie Area Seismic Evaluation for Shallow Hazards Anadarko Petroleum Corp. and Arco Alaska's proprietary 1994 and 1997-vintage 2D seismic coverage in the Moquawkie prospect area consists of 9 NW-SE oriented lines spaced approximately ~/~ to 1 aA miles apart and 2 SW-NE oriented lines. Seismic lines used in this evaluation are MQ94-2, 3, 4, 5, 7 and MQ97-1, 2, 3, 4, 5 & 6. This seismic data has been used to tie to wells on the Moquawkie structure. The primary wells are the Anadarko Lone Creek 1, Superior Chuit State 1, Superior Chuit State 2, Mobil Moquawkie 1, Mobil Moquawkie 2, Simpco East Moquawkie 1, West Moquawkie 1, Simpco Moquawkie 1 and Simpco Moquawkie 2. I conclude that, after examination of this data, there are no amplitude anomalies or other seismic signatures on any of the seismic lines that are typically related to the presence of gas accumulations in the shallow part of the section. In addition, no seismic anomaly or other signature is recognized for shallow gas encountered in the Anadarko Lone Creek 1 or Mobil Moquawkie 1. K~vin W. Martindale Sr. Staff Geophysicist Anadarko Petroleum Corporation Lone Creek #2 Drilling Well Plan Summary Field: Wildcat PTMD: 6,000' Wtr Depth: - Surface Location: 1956' FNL & 199' FWL Sec 30,TI2N,RIIW Prospect: Moquawkie PTVD: 6,000' Est. KB Elev: 443' Proposed BHL: 1956' FNL & 199' FWL Sec 30,T12N,R11W Lease/Well: Lone Creek #2 Spud Date: 9/5/00 Rig (Type): ~i~tD~ll,~ CC #~ L~.dmg Well Type: Exploratory Oil & Gas · Well Plan Mud Specifications BOP's Minimum Casing Desig~ Factors Frac CsgTst Max Max Test Electric Depth Hole Size Casing Casing Ratings. psi Cement Gradient MASP Pressure Mud Tvoe Pore Mud Pressure. psi Surveys TVD type inches Description (C) (B) (T)* (CroFt.) ppg psi psi Min sx: Barite/Gel Pressure Weight Annula, r Ram Type 200' Drilled 12.500 Conductor Casing 21.73 45.64 132.9! 300 11 N/A N/A Fresh Water Gelled 8.34 10.0 110 N/A ,~ Open 17.500 13.375" 68 ppf~ L-80, BT&CI 2,260 5,020 1545 Diverter DIL/Sonic/GR 1,000' Drilled 12.250 Surface Casing 4.94 2.63 14.46 600 12.5 610 1,500 Fresh Water Gelled 8.34 10.0 250 & 250 ~? 9.625" 40 ppf~ K-55, BT&C 2,570 3,950 486 3000 3000 DIL/Sonic/GR 5,000' I Drilled 8.500 First Inter./Prod. Casing 3.7..8. 2.41 5.59 800 15.8 2,297 3,000 Fresh Water Polymer 8.34 11.0 250 & 250 & 7" 26 ppt~ L-80, BT&C 5,410 7,240 604 3000 3000 Production Liner 6.12 3.38 _19.54 200 16.2 2,297 3,000 Fresh Water Polymer 8.34 11.0 250 & 250 & DIL/Sonie/GR 6,000' Drilled 6.000 5" 18 ppf~ L-80, SLX 10,500 10,140 351 3000 3000 *Lessor of Body Joint Tensile Ratin 1000 lbs. BOP Requirements Directional Plan Wellhd Interval API (Closure) see comments below Casing Points Class Size Rating (TVD) Configuration Surf to PBHL: KOP: TVD TVD MD N/A 20" 2M 0' - 200' TVD None Build dog/100' MD from , . TVD to ~ MD 200' 200' 1M 13.625" 5M 200' TVD Diverter Constant Angle degrees from MD to ~ MD 1,000' 1,000' 5M/SM 13.625" 5M 1000' TVD - TD R, Rd, A Drop dog/100' MD from' MD to MD 5,000' 5,000' BOP's will be tested to test pressures prior to drilling out Straight Hole from MD to MD 6,000' 6,000' each casing shoo and once every 7days thereafter. Fracture Gradient Test ppg pressure test will be performed afar drlg out below the 9-5/8" surface esg (~ 1000' but her°re drlgm°re than 49~ °f new h°le t° an equivalent pressure gradient °f 12.5 ppg IA pressure test will bo performed after drlg out below tho 7"first intermediate esg ~ 500ffbut before drlg moro than 49~ of new hole to an equivalent pressure gradient of 15.8 ppg Deviation surveys will be in accordance with 20 AAC 25.050. S:LAlaska\Drilling\Lone Creek 2L6,PD Calc LC 2 Drig Plan LONE CREEK #2 OUTLINE PROCEDURE 1. Move in and rig up Inlet Drilling Rig - #CC-1 (20" has been previously driven to 75'). 2. Drill 12 1/4"pilot hole, hole open to 17-1/2" hole, set and cement 13-3/8" conductor pipe to 200' RKB. 3. Cut off casing. NU 13-5/8" 5M SOW wellhead. NU and function test diverter system. Test to 110 psi. 4. Drill ~" hole to surface casing point ~ 1000' MD/TVD. 5. Rig up wireline and mn DIL/Sonic/GR. Rig down. 6. Run 9 5/8" casing and cement. 7. Install 9-5/8" hanger. Cut off9-5/8" casing. Install 13-5/8" 5M X 11" 5M casing spool. Test packoff. NU and test 13 5/8" 5M BOP stack. Notify AOGCC representative 24 hours in advance to witness BOPE test. 8. Drill cement and 25' of new formation with 8-1/2" bit. Perform formation integrity pressure test. 9. Drill 8-1/2" hole to total depth of 5000' MD/TVD. 10. Rig up wireline and mn DIL/Sonic/GR. Rig down. 11. Run and cement 7" casing. 12. Land casing in 11" casing head. Install 11" 5M X 7-1/16 5M robing spool. Test packoff. NU and test 13-5/8" 5M BOPE. 13. Drill cement and 25' of new formation with 6" bit. Perform formation integrity pressure test. 14. Drill 6" hole to 6000' MD/TVD. 15. Rig up wireline and mn DIL/Sonic/GR. Rig down. 16. Run injection packer on 4" drill pipe and dispose of reserve pit down 7" casing. 17. Set EZSV cement retainer in shoe of 7" and test casing to 3000 psi. 18. Revert to Completion Prognosis. Lone 'Creek Well #2, Moquawkie Prospect Proposed Wellbore Diagral,.. Anadarko Petroleum Corporation Surface Loc: 1956' FNL & 199' FWL Sec 30 T12N RllW 13 9 9 13 Quaternary (~ surface Beluga ~ ±168' TVD (+275'SS) Top of Tyonek ~ 1418 TVD (-975' SS) Top of Carya 2-4.2 Sd ~ 2293' TVD (-1850'SS) Top of Carya 2-9 E Mkr @ 4218' TVD (-3775'SS) Granite Point "C" Sands ~ 5168' TVD (-4725'SS) Juglans 1 B-2 ~ 5568' TVD (-5125'SS) 20" Structural ~ 75' Drive Pipe 9.0 - 10.0 ppg FWM 13-3/8" Conductor @ 200' TVD Cemented to surface 9.0 - 10,0 ppg FWM 9-5/8" Surface @ 1000' TVD Cemented to surface 10.0 - 11.0 ppg FWM TOL @ approximately 4,800' ('I'VD) 7" First Intermediate/Production Csg @ 5,000' (TVD) 10.0 - 11.0 ppg FVVM PBTD 5" Production Liner @ ~,-6000' (TVD) Cemented to TOL S:~Alaska~Drilling%one Creek 2\wellbore LC '2 LONE CREEK #2 DRILLING FLUID PROGRAM Interval Hole size = Casing Size = Mud type = 0'- 1,000' 17 ½" + 12-1/4" 20" ~ 75' + 13 3/8" ~ 200' + 9-5/8" ~ 1000' Fresh Water Gel Drilling Fluid Parameters: Weight: 9.0 - 10 ppg PV: 15- 25 cps YP: 15-45 lb/100R2 API Fluid Loss: n/c- 15cc Max Solids: <7% Spud the well with a flesh water spud mud consisting of bentonite and extender weighted to 9.0 ppg with barite. The initial viscosity should be in the 100-200 sec/qt, range then adjust as needed based upon actual hole cleaning requirements of the well. Continue to maximize pump rates to provide increased annular velocities to reduce mud viscosity requirements. Interval Hole size = Casing Size = Mud type = 1000' - 6000' 8-1/2" + 6" 7"~ 5000' Fresh Water Gel/Polymer Drilling Fluid Parameters: Weight: 10.5 - 11.0 ppg PV: 15- 20 cps YP: 10-20 lb/100ft2 pH: 8.5 - 9.5 API Fluid Loss: ~ <5 cc Max Solids: <7% Clean up the surface system via dilution and mechanical separation prior to drilling ahead in the 8-1/2" hole, building new volume as required with bentonite. When drilling out, allow the spud mud to blend with the re-conditioned surface mud and drill ahead with a fresh water Gel system. LONE CREEK CASING & PRESSURE INgO~T[ON Setting Depth SiZe Specifications, Top Bottom ,., Hole Casin~] Wei~]ht Grade Couplin9 Lenl~th MD TVD MD TVD Drive 20" 92 ppf X-56 WELD 75' Surf. Surf. 75' 75' 17 1/2" 13 3/8" 68 ppf L-80 BTC 200' Surf. Surf.. 200' 200' 12 1/4" 9 5/8" 40 ppf K-55 BTC 1000' Surf. Surf. 1000' 1000' 8 %" 7' 26 ppf L-80 BTC 5000' Surf. Surf. 5000' 5000' 6" 5" 18 ppf L-80 SLX 1200' 4800' 4800' 6000' 6000' .,'.i,~ Casing Jgint"Strength Body Strength Burst Collapse I,. K lbs K lbs ps~ £s~ 13 3/8" 68~ L-80 BTC 1545 1556 5020 2260 9 5/8" 40~ K-55 BTC 486 630 3950 2570 "~- 26~ L-80 BTC 641 604 7240 5410 '" "5" 1~ L-80 SLX 35 ! 422 10,140 ]0,500 Casing Specifications from USS Seamless Oil CoUmry Tubular Products Publication and Hydril Tubular Products Publication. Rig' I'nlet Drilling CC #1 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6OOO 6500 7000 Spud RR Lone Creek #2 1' Days vs Depth ~ Peffo~eumC~poration -- Proposed Set 9-5/8" @ 1000' Set 7" @ 5000' ooo, 0 2 4 6 8 10 12 14 16 18 20 2224 26 28 30 32 34 36 38 40 Days days vs depth LC 2.xls 7/12/00 Lone Creek #2 Casing & Pressure Calculations Conductor Casing Casine Specifications: Conductor Casing Set from GL to 200' MD, TVD Collapse Rating = 2~260 psi Burst Rating = 5,020 psi Joint Strength = 1,545,000 lbs Body Strength = 1,556,000 lbs Collapse Design = 100% 13.375" 68 ppf, L-80, BT&C Maximum Anticipated Surface Pressure below Conductor Casing: 13.375" 68 ppf, L-80, BT&C set at 200' TVD 12.250 inch hole drilled to 1,000' TVD Fracture Gradient at Surface Shoe -' 11.0 ppg EMW Mud Weight at next Casing Point = 10.0 ppg Fracture Pressure at Shoe (Pr) = 11.0 x 0.052 x Gas Gradient = 200' x 0.04 psi/it MASP = 114 - 200' = 114 psi = 8 psi = 106 psi Casing Test Pressure: Test diverter to 110 psi Note: diverter to be rigged up on this casing string Casing Design & Safety Factor Calculations: NOTE: Conductor casing will be landed and cemented to surface to supplement stability and collapse design. Collapse Design = ( Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 200' x 100% 10.0 x 0.052 ) = 104 2,260 psi / 104 psi = 21.73 Burst rating / MASP (or test pressure, which ever is greater) 5,020 psi / 110 = 45.64 Lessor of joint or body strength / running load 1,545,000 lbs / 68.0 lbs/ff x 200' x psi 0.85 = 132.91 DESIGN FACTORS Collaose ,Burst Tension. 21.73 45.64 132.91 C:~:XCEL~DRLGPLAN~APD Calc LC 2.xls - 7/13/00 Lone Creek #2 Casing & Pressure Calculations Surface Casing Casin~ Suecifications: Surface Casing Set from RKB to Collapse Rating = Burst Rating = Joint Strength = Body Strength = Collapse Design = 1,000' MD, TVD 2,570 psi 3,950 psi 486,000 lbs 630,000 lbs 100% evacuation 9.625" 40 ppf, K-55, BT&C 70% = 2765 psi) Maximum Anticipated Surface Pressure below Surface Casing: 9.625" 40 ppf, K-55, BT&C set at 8.500 inch hole drilled to Fracture Gradient at Surface Shoe Mud Weight at next Casing Point Fracture Pressure at Shoe (Pf) Gas Gradiem MASP 1,000' 5,000' TVD TVD = 12.5 ppg EMW = 11.0 ppg = 12.5 x 0.052 x = 1,000' x 0.04 psi/fi = 650 - 1,000' = 650 psi = 40 psi 40 = 610 psi Casing Test Pressure: 1,500 psi for 30 min. prior to drilling out of the casing shoe Casing Design SafeW. Factor Calculations: NOTE: Surface casing cemented to surface to supplement stability and collapse design. Collapse Design = 1,000' x 100% x 10.00 Safety Factor = 2,570 psi / 520 psi = 4.94 Burst Design = Burst rating / MASP (or test pressure, which ever is greater) Safety Factor = 3,950 psi / 1,500 psi = 2.63 Tension Design = Lessor of joint strength or pipe body / nmning load Safety Factor = 486,000 lbs / 40.0 lbs/ft x 1,000' x 0.052 = 520 psi 0.84 = 14.46 DESIGN FACTORS Collapse 4.94 Burst 2.63 Tension 14.46 S:~,laska\Drilling\Lone Creek 2~PD Calc LC 2.xls Surf Lone Creek #2 Casing & Pressure Calculations First Inter./Prod. Casing Casin~ Soecifications: First Inter./Prod. Casing 7" 26 ppf, L-80, BT&C Set from RKB to 5,000' TVD, Collapse Rating = 5,410 psi Burst Rating = 7,240 psi Joint Strength = 641,000 lbs Body Strength = 604,000 lbs Collapse Design = 50% evacuation 5,000' MD 70% = 5068 psi) Maximum Anticipated Surface Pressure below First Intermediate Cosine: 7" 26 ppf, L-80, BT&C set at 5,000' TVD 6.000 inch hole drilled to 6000' TVD, then set 5" production liner at Fracture Gradient at 5,000' = 15.8 ppg EMW Mud Weight at Proposed Total Depth = 11.0 ppg Pore Pressure at prospective production depth (Pp) = 8.34 x 0.052 x Fracture Pressure at Shoe (Pr) = 15.8 x 0.052 x 60OO 5,000' 6000' TVD 2,602 4,108 psi psi From the Weymouth Equation which calculates MASP in production mode: e .0000347 GZp = 2,602 1 ~ e .0000347 x .6 x 6,0 = 2,297 psi Or from the modified Weymouth Equation with loss of circulation during a kick the MASP is calculated as follows: MASP(Ps)= Pr ~ 1 _~~ X ~ 4000 e .0000347 GZp Zp = 4,108 1 X 4000 e .0000347 x.6 x 5,00 5,000' = 3,311 psi (pore pressure ~ 6,000' can only generate 2297 psi ~ surface) Casing Test Pressure: 3,000 psi for a 30 minute period prior to drilling out of the casing shoe Cosine Design Safe~, Factor Calculations: Collapse Design = Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 5,000' x 50% x 11.0 5,410 psi / 1,430 psi = 3.78 Burst rating / MASP (or test pressure, which ever is greater) 7,240 psi / 3,000 psi = 2.41 Lessor of joint strength or pipe body / running load 604,000 lbs / 26.0 lbs/ff x 5,000' x 0.052 = 1,430 psi x 0.83 = 5.59 DESIGN FACTORS Collapse 3.78 Burst 2.41 Tension 5.59 S:~laska\Drilling~one Creek 2V~PD Calc LC 2 1st Inter Lone Creek #2 Casing & Pressure Calculations Production Liner Casing Snecifications: Production Liner 5" 18 ppf, L-80, SLX Set from 4,800' TVD, MD to Collapse Rating = 10,500 psi Burst Rating = 10,140 psi (6 70% = Joint Strength = 351,000 lbs Body Strength = 422,000 lbs Collapse Design = 50% evacuation 6,000' 7098 TVD, MD psi) Maximum Anticipated Surface Pressure below Casing: 5" 18 ppf, L-80, SLX set from 4,800' TVD, MD to Mud Weight at Total Depth = 11.0 ppg Fracture Pressure at 7" Shoe (Pt) = 5,000' x 0.052 x Pore Pressure At TD (Pp) = 6,000' x 0.052 x 8.34 6,000' TVD, MD 15.8 ppg= 4,108 psi ppg = 2602 psi From the Weymouth Equation which calculates MASP in production mode: MASP (Ps) = Pp = 2,602 e .0000347 Gzp e .0000347,0.6 6,00 2,297 psi Top Of Liner Casing Test Pressure: TOL Test Pressure = Fracture Pressure at the 7" Shoe + 500 psi minus hydrostatic pressure due to mud = ( 4,108 psi + 500 psi ) - ( 11.0 ppg x .052 x 5,000' ) = 1,748 psi TOL Casing Test Pressure: 3,000 psi with an 11.0 ppg mud hydostatic for a 30 minute period Casing Design Safety Factor Calculations: Collapse Design = Safety Factor = Burst Design = Safety Factor = Tension Design = Safety Factor = 6,000' x 50% x 11.0 x 0.052 = 10,500 psi / 1,716 psi = 6.12 Burst rating / M_ASP (or test pressure, which ever is greater) 10,140 psi / 3,000 psi = 3.38 Lessor of joint strength or pipe body / running load 351,000 lbs / 18.0 lbs/fi x 1,200' x 0.83 DESIGN FACTORS Collapse Burst Tension 6.12 3.38 19.54 1,716 psi = 19.54 C:\EXCEL\DRLGPLAN~APD Calc LC 2 7/10/00 Conductor Casing WELL DATA LONE CREEK #2 CEMENTING PROGRAM DEPTH 200' MD /TVD HOLE SIZE 17 1/2" PIPE SIZE 13 3/8" OD, 68 ppf MINIMUM VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT 300 cf Sufficient to circ to surface CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives Surface Casing WELL DATA DEPTH 1000 'MD / TVD HOLE SIZE 12 ¼" PIPE SIZE 9 5/8"OD, 40 ppf CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives MINIMUM VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT 600 cf Sufficient to circ to surface Production~ntermediate casing WELL DATA DEPTH 5000'MD / TVD HOLE SIZE 8-1/2" PIPE SIZE 7"OD, 26 ppf VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT 800 cf Sufficient to circ to 1000' CEMENT Lead: 12.5 ppg - Class G + additives Tail: 15.8 ppg - Class G + additives Production Liner WELL DATA DEPTH 6000' MD / TVD HOLE SIZE 6" PIPE SIZE 5"OD, 18# VOLUME REQUIRED TOTAL VOLUME TOP OF CEMENT 200 cf Sufficient to circ to TOL CEMENT Slurry_: 15.8 ppg - Class G + additives PLEASE REFER TO YOUR VENDOR 5VOMBER . IN ALL CORRESPONDENCE ABOUT T~S ~.CCOUNT. VW. NDOR NO. 24002 Anadarko Petroleum Corporation P.O. BOX 1330 Houston, TX 77251-1330 STATE OF ALASKA OIL & GAS VOUCHER/ BATCH# VENDOR INV $/ INV DATE REMARKS iCliK ,-"'A:P!'S [ CHK ~ 07-AP-1095 CKRQ07/05/00 07/05/00 07-36497 PERMIT TO DRILL LONE CREEK ~2 TOTAL INVOICES PAID 24002 252964 TOTAL PRIOR PMTS NET AMOUNT & DISCOUNTS AMOUNT 100.00 0.00 100.00 100.00 ~9'[,,1 '1~11~ [rlll] 'i [et l~[,l II IIlI~l! W~I=~i II; [,,T-"E~,~ ~ ~,,~1 ;i ii; [llt,] I&V/,~ i = :i?~ [,~;I :El] ~ I ;i :i'l ~ ;{.-9 ;~,:1111 ~ I ;1=1 ;f,!et =III ;;111; I ~-'tl IIIIl&l J~TiI=~ i d; F:T.,.'~,31 :! I[ I J :l:~;Tll :<t9 ;[llli ~ll]~l]~ &Vi-Ii ~ :1 './.'~ '.J ~ ;,., Petroleum Corporation · ' P.O. BOX 1330 Houston, TX 77251-1330 i DATE / .':.,,::?.:'....,,:...<, ........ 0 7 / 0 7 / 0 0 ./.;:':....: ,;::'.[:". ~::' . TO T~E OllDP~.0F.~.,.' ~' ' : ':~':i;!i: ::i::. .:" ..... STATE OF :':~S:~':~'O'IL & CONS ERVAT I ON':'" 'COMM I S S I ON "~""', .::'.:' '::~ '" ": 3 0 01 PORCUPINE ' DRIVE .... ANCHORAGE, AK 99501 Me~o, sa~ s.u. 60-,6o i CHECK NO Pittsburgh, PA 433 ' AMOUNT ********$100.00 AUTHORIZED REPRESENTATIVE(S) OF T~E COMI~ANY LONE CREEK #2 ATTACHMENTS 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. UNIT BOUNDARY/LOCATION PLATS DISPOSAL REQUEST FORMATION WATER SALINITY LETTER SEISMIC EVALUATION FOR SEISMIC HAZARDS DRILLING WELL PLAN SUMMARY OUTLINE PROCEDURE WELLBORE SCHEMATIC DAYS VS DEPTH GRAPH DRILLING FLUIDS PROGRAM PRESSURE PROFILE CASING AND PRESSURE INFORMATION/CALCULATIONS CEMENTING PROGRAM OFFSET WELL PRESSURE PROFILE DRILLING ACTION PLAN BOP EQUIPMENT AND DIAGRAMS INLET DRH.LING DRILLING FLUID SYSTEM DESCRIFFION AND DIAGRAM iWELL PERMIT CHECKLIST COMPANY ,~///t,t~:D~'~,,~O WELL NAME~,~'~2- PROGRAM: exp v/dev ~ redfll · serv ~ wellbore sag. ann. disposal para req. FIELD & POOL ADMINISTRATION ! A~.~. INIT CLASS ~'~/~ /.,~/.4~'~)d-~T" GEOL AREA 1. Permit fee attached ....................... ~ N . Lease number appropriate ................... ~ N Unique well name and.number .................. ~ N_ 41 Well located in a defined pool .................. ~ ,,~-/.~ -,,~z~c.. ~:/c-Z>c~*7'- · _ . . 5. Well located proper distance from drilling unit boundary .... ~ ~,'3~.~W-p~ ./~ ~ ~._,,~C.. Z...~'.~.-~-,5'- ,' ...~'~,,,~r~~ ,~'~¢/~'/~: d~re. c,~'~-~ 6. Welllocated proper distance from other wells .......... ~ N .~ ~. Sufficient acreage available in drilling unit ............ ~,, (...~N ~,J~.,~...~: ~ /~_~.-/-z~..~..c¢_~. ~-,=(/.,~7.7.¢' -~,~,u/,:'¢ E~,'~,~,,~._,~., 4Z.~._~r' ~-,,t~/'..~.~ ,~s'~. · If deviated, is wellbore plat i,l~ded .............. /V',//..z..~N~/'/~,~5 1~)i Operator only affected part~::~"~ ............... '. ' ~______./N,~_.."~z~ ,c~_~__c- Operator has appropriate bo-~din force ............. ~(~N~'[, ...~,,). 11. Permit can be issued without conservation order ........ (~Y_~N ..<,.,b.,~,Y- ,~L_</.~_..~ ?~,,.~ ,~,~w ol' =tf'~-,~-' -(-fd~,'/~.. ~ '~./~,,~& Permit can be issued without administrative approval ...... _~i~.~N 7.. ~i- 12.13. Can permit be. approved before 15-day wait ........... . (~ E--N--G-~N E~ 14. Conductor string provided ................... {~ N . . , . 15. Surface casing p. ro!ectsal!k, nownUSD, W.s..;... ....... ~ -~_~ 16. CMT vol adequate to circulate on conductor ~, sun csg .... .. L~ r~ · . .' 17. CMT vol adequate to tie-in long string to surf csg ..... ~-..', ~ N' 18. CMT will cover all known productive horizons ....... . . . (,~ N I ' 19. Casing designs adequate for C, T, B & permafrost... ~ . . . 0'.~ N I 20. Adequate tankage or reserve pit ................. (~) N I 21. If a re-drill, has a 10-403 for abandonment been approved...' _--Y--N 22. Adequate wellbore separation proposed ............. ~ N . I 23 If diverter required does it meet regulati°ns .......... Y ('N") to)" \\,-,~, %',,"c~. ~' c3~,\'{~,,..~b~,c~\~z ~ \~,.,~5'x~r~ , e.,~c~'t'~c,~-., c~c,%e..~"%~.~ ~t'~c..c~w~--,e.~c~ II 241 Drilling fluid progr'~m schematic & equip list adequate ..... ~.~ . ~-.-~..~-~. ~-,~ ~ ';,,..,~,.~z"'~ ~ - ~.- ~ (~--~er( N "" [I ' 25. BOPEs, do they meet:.regulation ................ II/~P..P.B DATE 26. BOPE press rating appropriate; test to ~(~(._~ ~sig. ~ N ~,& I~%'~ -_ D ~%'-~c,~, I1~'~-~ ~//~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N II " 28. Work will occur without operation shutdown ........... (,.YJ N_ . .... . ..' I1(~~ 9['2.~.~) 29. Is presence of H2S gas probable ................. Y IIGEOLOGY 30. Permit can be issued wlo hydrogen sulfide measu.!'~s ..... L'~ N . . , . . ~ , ~.,,~ ~ ~ / , / / .;/., ~-.,~1 I1~ 31. Data presented on potential overpres~u[e zones'~.. .... (~ II 32. Seismic analysis of shallow gas zon .e~ ........ .".. ~ N .. IIAP, PR DATE 33. Seabed condition survey (if.off-shore) ............. ,A/,~ II /'A~"~ ~"~'~)~,~ 34. Contact namelphone for weekly progress reports [exploratory only](~N I[ AN~NU LAR DISPOSALS5. With proper cementing records,, this plan II ~ ~ ' (A) will contain waste in a suitable receiving zone; ....... ~ N ' , II APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... II" . to surface; .1~ II w~ ~)/7..~Oo (C) will not impair mechanical integrity of the well used for disposal; II ~' ' (D) will not damage producing formation or impair recovery from a II pool; and . I] (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ' ~ N ~1 GEOLOGY.; ENGINEERING: UlClAnnular COMMISSION:"- comments/Instructions' . , , . c:~nsoffiCe\wordian~diana\checklist (rev. 02117100) .. ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. LONE CREEK #2 MOQUAWKIE FIELD Section 30.T12N-R11W, SM Kenai Borough, Alaska October 8, 2000 Tim Smith, Sr. Logging Geologist Steve Hamer, Sr. Logging Geologist Lowell Price, Logging Geologist Nicholas Atkinson, Logging Analyst EPOCH TABLE OF CONTENTS Anadarko Petroleum Corporation Lone Creek #2 Moquawkie Field Kenai Borough, Alaska Well Resume Page 1 Summary and Conclusions Page 2 Lithology Summary Page 4 Daily Activity Summary Page 21 Days vs. Depth Mud Record Page 25 Page 26 Survey Record Page 27 Bit Record Page 29 Mudlog Appendix 1 l~Fell Rest#~ie WELL RESUME Operator: Well Name: Field: Region: Location: Borough: State: Elevations: APl Number: Spud Date: Completion Date (TD): Total Depth: Bottom Hole Formation: Company Representatives: Company Geologist: Contractor: Drilling Rig: Toolpushere: Mudlogging Contractor: Logging Geologists: Unit # Services Provided: Mud Company: Cement Company: Wireline Company: Anadarko Petroleum Corp. Lone Creek #2 Moquawkie Upper Cook Inlet 1,956' FNL, 199' FWL Section 30-T12N-R1 tW, SM Kenai Borough Alaska RKB: 412.9' AMSL GL: 409' AMSL #50-283-20098-00 9112100 1018100 5,000' MD Tyonek Bob Wiley Peter Leach John Hartner Inlet Drilling CC #1 Joe Steiner Epoch Well Services, Inc. Tim Smith, Steve Harner, Lowell Price, Mark Lindloff Unit #12 (FID) Total Gas Detection (FID) Gas Chromatography MI B-J Services Schlumberger Summary a~td Cottclusions SUMMARY AND CONCLUSIONS ANADARKO LONE CREEK #2 Anadarko Petroleum Corporation spudded the Lone Creek #2 well on September 12, 2000 with Inlet Drilling Company's Rig CC #1. The objectives of this exploratory Moquawkie prospect well were to evaluate potentially gas bearing sands in the Tyonek Formation. The well is an offset to the Lone Creek #1 well, a discovery well drilled in 1998. The structural setting for this well is on the southern end of a tightly folded north- South trending anticline On the west side of the Cook Inlet Basin. The section penetrated in this well consisted of Quaternary glacial outwash deposits, the Beluga Formation and the Tyonek formation. Drilling progressed well with no major rig delays, and a Total Depth of 5.000' MD (Driller) was reached on October 8, 2000 in the Tyonek Formation. At the time of this writing, electric logs have been completed prior to abandonment of the well. Epoch Well Services, Inc. provided DML (Digital MudloggingTM) services consisting of 2 geologist, 24-hour (FID) Total Gas Detection, (FID) Gas Chromatography and sample collection services. RIGWATCH Explorer remote data telecommunications services were also provided to the Anadarko offices in Houston and Anchorage and to partners Phillips Alaska, Inc. in Anchorage. Epoch commenced logging at spud from zero feet to Total Depth at 5,000'. The geological sampling program consisted of collecting 2 unwashed wet sample cuts and 3 washed and dried sample cuts. In addition, 37 gas samples were collected in Mylar bags for isotopic ratio analysis. These gas samples were collected at the discretion of the consulting geologist through any significant gas shows, The well spudded in surface glacial outwash deposits, and surface hole was drilled to 245' to insure all surface gravels and other potential aquifers were cased off. Based on samples, the base of the gravel assemblage appeared to be at 130", with a sudden influx of clay and tuffaceous claystone with thin interbeds of coal. The assumption is the top of the Beluga formation was encountered at approximately 130', however, this contact was not definitive in samples. The influx on the first noticeable coals was the basis for this pick. The upper portions of the Beluga consisted of interbedded tuffaceous claystones, co~ls, and proportionately thin volcaniclastic sands. Numerous calcareous ash fall tuffs were noted in this section as sell. Lower portions of the Beluga consisted of an increasing occurrence of fining-upwards volcaniclastic sands, coals and tuffaceous clays. The Beluga sands produced background gases ranging from 3-26 units. The Beluga drilled up at rates varying from 160 to 4 feet per hour. No significant hydrocarbon shows were encountered in the Beluga. The appearance of a thick lignitic coal at 1753' marked the top of the Tyonek, which consisted of well-developed coal seams, conglomeratic sand, tuffaceous clays and minor amounts of calcareous ashfall tuffs. The Tyonek drilled up at rates varying between155 feet per hour and 6 feet per hour through the calcareous tuffs. Faster drilling rates were typically associated with coals and the sand/conglomerate assemblages. The Tyonek produced a methane-dominated background gas ranging between 5 units and 187 units. Lithology Sumtnary LITHOLOGIC SUMMARY ANADARKO PETROLEUM CORPORATION LONE CREEK #2 QUATERNARY ALLUVIUM/GLACIAL OUTWASH 100' CONGLOMERATE BLACK TO DARK GRAY; PEBBLES TO COARSE GRAIN SAND; DOMINANTLY WELL ROUNDED TO SUBROUNDED, SOME BROKEN FRAGMENTS; POORLY TO MODERATELY WELL SORTED. TOP BELUGA AT 130' 130' COAL DARK BROWN TO BLACK; FIRM TO MODERATE HARD; BRITTLE TO CRUMBLY; SMALL TO LARGE IRREGULAR TO BLOCKY CUTTINGS; DULL TO EARTHY LUSTER; SMOOTH TEXTURE. 150' CLAYICLAYSTONE GRAY TO LIGHT GRAY; OCCASIONALLY A BROWNISH GRAY; DOMINANTLY SOFT OCCASIONALLY FIRM SUBROUNDED LUMPS; SMOOTH TO MODERATELY GRITTY TEXTURE; NON CALCAREOUS; COAL AND TRACE CARBONACEOUS SPECKS IMBEDDED INTO SAMPLE. 190' COAL DARK BROWN TO BLACK; FIRM TO MODERATELY HARD; BRITTLE TO CRUMBLY; SMALL TO LARGE IRREGULAR TO BLOCKY CUTTINGS; SOME PIECES HAVE A PLATY NATURE WHEN BROKEN; DULL TO EARTHY LUSTER; SMOOTH TO WOODY TEXTURE. 250' CONGLOMERATIC SAND MEDUIM DARK GRAY TO VERY DARK GRAY; DOMINANTLY AS SCATTERED IGNEOUS LITHIC PEBBLES UP TO 21mm WITHIN A LOWER MEDUIM TO UPPER COARSE GRAINED LITHIC SAND MATRIX; POORLY SORTED; SUBANGULAR TO WELL ROUNDED WITH FINER GRAINS TENDING TO BE MORE ANGULAR; MODERATE TO HIGH SPHERICITY; MOSTLY DARK GRAY TO BLACK VERY FINE GRAINED MAFIC RICH IGNEOUS LITHIC DETRITUS WITH SCATTERED TRANSLUCENT, MILKY WHITE AND CLEAR QUARTZ GRAINS; APPARENT MODERATE AMOUNTS OF LIGHT TO MEDUIM LIGHT GRAY HYDRATING SMECTITIC INTERGRANULAR CLAY; 60-80% IGNEOUS LITHIC DETRITUS; 10-30% VARIOUS QUARTZ; 1-5% REDDISH ORANGE FERRO-SILIC DETRITUS; 1-5% FELDSPATHIC MATERIAL. 330' ,. COAL VERY DARK BROWNISH BLACK, DARK GRAYISH BLACK AND BLACK; SOFT AND CRUMBLY WHERE LIGNITIC AND VAGUELY WOODY TO FIRM, SPLINTERY AND BRITTLE AS SUBBITUMINOUS GRADE MATERIAL; DULL AND MATTE TO OCCASIONALLY VERY SLIGHTLY GLOSSY; MOSTLY VERY FINELY GRAINY AND PITTY TO MODERATE SMOOTH; COMMON AS BLOCKY, TABULAR AND STEP- PLANAR CUTTINGS; GENERALLY WOODY AND LINEATED SURFIClAL PARTING FACES WITH OCCASIONALLY SUBCHONCHOIDAL TO CONCHOIDAL END BREAK; APPEARS ASHY WHITE AFTER FLAME TEST WITH MODERATE BITUMINOUS ODOR. 390' TUFFACEOUS CLAYSTONE VERY LIGHT GRAY TO LIGHT GRAY; VERY SOFT TO SOFT, SOUPY, MUSHY AND COLLOIDAL MATERIAL IN SAMPLES WITH LOW COHESION AND MODERATE TO HIGH ADHESION; VERY QUICKLY HYDRATES AND EXPANDS iN FRESH H20; MOSTLY SMOOTH TO VERY FINELY SILTY AND GRAINY; GENERALLY DULL AND EARTHY DRY AND MODERATE GLOSSY WHEN WET; OCCASIONALLY HIGH AMOUNT OF SUSPENDED SILT AND FINE SAND SIZE VOLCANICLASTIC DETRITAL MATERIAL GRADING TO BOTH TUFFACEOUS SILTSTONE AND TUFFACEOUS VOLCANICLASTIC SANDSTONE; COMMON DISSEMINATED CARBONACEOUS MATERIAL THROUGOUT; OCCASIONALLY DURABLE CALCAREOUS VARIETIES. 470' VOLCANICLASTIC SAND OVERALL VERY LIGHT GRAY TO MEDUIM LIGHT GRAY; LOWER FINE TO LOWER COARSE, MOSTLY UPPER FINE TO UPPER MEDUIM; MODERATELY SORTED; ANGULAR TO ROUNDED; MODERATE TO LOW SPHERICITY; MOSTLY TRANSLUCENT, CLEAR AND MILKY WHITE QUARTZ WITH ABUNDANT DARK GRAY TO BLACK IGNEOUS LITHIC DETRIAL GRAINS, REDDISH ORANGE FERRO-SILICS, CHALKY WHITE TO YELLOWISH GRAY FELDSPATHICS AND MINOR GREENISH GRAY MATERIAL; COMMON VERY LIGHT GRAY SMECTITIC HYDRATING MATRIX CLY; SCATTERED CARBONACEOUS GRAINS; PROBABLE MATRIX SUPPORTED IN PLACE BUT AS UNCONSOLIDATED MATERIAL IN SAMPLES MATRIX CHARACTER DIFFICULT TO DETERMINE. 570' TUFFACEOUS SlLTSTONE LIGHT GRAY TO MEDUIM LIGHT GRAY OVERALL; EASILY FRIABLE TO OCCASIONALLY MODERATE HARD WHEN MATRIX CLAYS ARE CALCAREOUS; VERY FINELY GRAINY TO MODERATE SMOOTH; DULL AND EARTHY WITH DISSEMINATED MICROSPARKLES FROM SUSPENDED REFLECTIVE QUARTZ GRAINS AND OTHER DETRITAL GRAINS; GENERALLY IS POORLY CEMENTED BUT OCCASIONALLY BECOMES VERY CALCAREOUS AND GRADES TO CALCAREOUS TUFFACEOUS MUDSTONE / CLAYSTONE; COMMON SCATTERED CARBONACEOUS DEBRIS INCLUDING DISCRETE PARTICULATE MATTER AND WOODY MATERIAL; RARLY TRANSLUCENT TO VAGUELY CLEAR YELLOWISH AND REDDISH-BROWN AMBER. 640' CALCAREOUS TUFF PALE YELLOWISH BROWN, GRAYISH YELLOW, YELLOWISH ORANGE AND VERY PALE ORANGE WITH OCCASIONALLY DUSKY BROWN TO BLACK CARBONACEOUS MATERIAL IMBEDDED LONG CONTACT SURFACES; HARD TO VERY HARD; CRYPTOCRYSTALLINE TO APHANITIC; MATTE AND VERY FINELY GRAINY; DULL WITH FEW DISCERNABLE MICROSPARKLES; TOUGH, RIGID, BLOCKLY, SHARP EDGED, CONCHOIDAL AND WEDGLIKE CUTTINGS OF HIGH DENSITY; APPEARS AS COLLOID OF CaCO3 AND CLAY SIZE PARTICULATE MATTER WITH MINOR VERY DARK BROWN TO BLACK MICROSPECKS. 710' TUFFACEOUS SlLTSTONE VERY PALE YELLOWISH BROWN TO PALE BROWN WITH SCATTERED DARK BROWNISH BLACK TO BLACK CARBONACEOUS FLAKES, GRAINS AND SPECKS; MOSTLY VERY EASILY FRIABLE BUT OCCASIONALLY IS FIRM TO HARD WHERE CALCAREOUS; VERY FINELY GRAINY AND OCCASIONALLY SANDY TO MODERATE SMOOTH AND CLAYEY; GENRALLY DULL WITH SCATTERED MICRO-SPARKLES; COMMON DARK BROWNISH BLACK TO BLACK CARBONACEOUS MATERIAL. 760' TUFFACEOUS CLAYICLAYSTONE LIGHT BROWNISH GRAY; VERY SOFT TO SOFT, OCCASIONALLY SLIGHTLY FIRM; LUMPY TO CLUMPY, ROUNDED IRREGULAR TO SUB-BLOCKY FRACTURE; EARTHY LUSTER, OCCASIONALLY SCATTERED MICROSPARKLES; CLAYEY TO SMOOTH TEXTURE; THICK BEDDED; FIRMER CUTTINGS; SLIGHTLY CALCAREOUS. 800' COAL DUSKY YELLOWISH BROWN TO GRAYISH BROWN; BITUMINOUS TO SUB- BITUMINOUS; MODERATE HARD TO FIRM; BRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR; DULL TO SLIGHTLY GLOSSY. ,8,40' CALCAREOUS TUFF YELLOWISH GRAY TO GRAYISH ORANGE; HARD TO VERY HARD, OCCASIONALLY FIRM; BRITTLE TO OCCASIONALLY CRUMBLY; IRREGULAR TO SUB-BLOCKY FRACTURE; TABULAR TO WEDGE-LIKE CUTTINGS HABIT; EARTHY LUSTER; MICROCRYSTALLINE TO CRYPTOCRYSTALLINE. 880' SAND MEDUIM GRAY TO MEDUIM DARK GRAY OVERALL, WITH INDIVIDUAL GRAINS RANGING FROM TRANSPARENT TO FROSTED WHITE TO GRAYISH BLACK; LOWER MEDIUM TO UPPER MEDIUM, OCCASIONALLY RANGING DOWN TO LOWER FINE GRAINED; FAIR TO WELL SORTED; ANGULAR TO SUBANGULAR, OCCASIONALLY SUBROUND; MODERATE TO HIGH SPHEROIDAL SPHERICITY OVERALL WITH RARE DISCOIDAL SPHERICITY; UNCONSOLIDATED MAFIC/LITHIC FRAGMENTS. PREDOMINANTLY 930' TUFFACEOUS CLAYSTONE LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SOFT AMORPHOUS LUMPS; CLUMPY TO CURDY TO OCCASIONALLY GELATINOUS TEXTURE; MODERATELY COHESIVE, MODERATE ADHESIVE; EARTHY LUSTER; CLAYEY TO COLLOIDAL TEXTURE; THICK BEDDED; SLIGHTLY CALCAREOUS. 1040' COAL DARK BROWNISH BLACK TO BLACK WITH OCCASIONALLY DARK GRAYISH HUE; MODERATELY SOFT TO VERY FIRM; MOSTLY AS RIGID, BRITTLE, SPLINTERY, BLOCKY, TABULAR, IRREGULAR WEDGELIKE AND CONCHOIDAL CUTTINGS; DOMINANTLY SMOOTH TO MATTE AND OCCASIONALLY WOODY TO EARTHY; GLOSSY AND MODERATE SHINY TO FAIRLY DULL WITH RELATIVELY LOW SURFIClAL REFLECTANCE; MOSTLY SUBBITUMINOUS TO BITUMINOUS WITH OCCASIONALLY WOODY AND EARTHY LIGNITIC MATERIAL; BECOMES ASHY GRAYISH WHITE WITH NON TO FAINT WHITE CLEAN NONSOOTY SMOKE AND WEAK BITUMINOUS ODOR. 1100' SAND OVERALL MEDUIM LIGHT GRAY TO MEDUIM GRAY WITH COMMON DARK GRAY TO BLACK DETRITAL GRAINS; LOWER VERY FINE TO UPPER MEDUIM; ANGULAR TO SUBROUNDED; MODERATE TO POORLY SORTED; MODERATE TO LOW SPHERICITY; GENERALLY APPEARS AS SUSPENDED SAND GRAINS WITHIN A VERY LIGHT GRAY TO GRAYISH WHITE LARGELY SMECTITIC CLAY MATRIX; MOSTLY TRANSLUCENT, CLEAR AND MILKY WHITE QUARTZ WITH COMMON DARK GRAY TO BLACK ALTERED IGNEOUS DETRITAL MATERIAL ANDMINOR GRAY TO 'CHALKY WHITE FELDSPAR; MINOR REDDISH ORANGE TO REDDISH BROWN FERO-SILIC GRAINS (POSSIBLY ALTERED VOLCANICS); SCATTERED VERY LIGHT YELLOWISH BROWN TO VERY PALE ORANGE AND DARK GRAY HARD CALCAREOUS TUFF AND CALCAREOUS TUFFACEOUS CLAYSTONE; OCCASIONAL DARK BROWNISH BLACK TO DUSKY BROWN DETRITAL COAL AS WELL AS SUSPECTED THIN INTERBEDDED COALS. 1230' GRANULE BEARING CALCISILIC SANDSTONE OVERALL MEDUIM GRAY TO VERY DARK GRAY; FINE UPPER TO VERY FINE LOWER TO COARSE LOWER WITH SCATTERED UPPER COARSE TO SMALL GRANULES UP TO 6MM; POORLY TO MODERATELY SORTED; ANGULAR TO SUBROUNDED; MODERATE TO LOW SPHERICITY; VERY WELL CEMENTED BY CaCO3 AND SiO2; VERY HARD, RIGID, ROUGH EDGED, BLOCKY TO IRREGULAR WEDGELIKE AND GRAINY CUTTNGS; MOSTLY DARK GRAY TO GRAY BLACK MAFIC RICH IGNEOUS LITHIC GRAINS WITH TRANSLUCENT, CLEAR AND MILKY WHITE QUARTZ; OCCASIONALLY OPAQUE, LIGHT GRAY TO CHALKY WHITE FELDSPAR;MINOR BLACK TO BROWNISH BLACK DETRITAL COAL; TRACE PALE YELLOWISH BROWN TO PALE ORANGE CALCAREOUS TUFF LITHICS; TIGHT GRAIN SUPPORT WITH MOSTLY MINOR TO NO MATRIX MATERIAL; POSSIBLY VOLCANICLASTIC. 1310' SAND MEDUIM DARK GRAY TO MEDUIM LIGHT GRAY OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TO WHITE TRANSLUCENT TO MEDUIM DARK GRAY TO DARK GRAY, SOME GRAINS PINKISH GRAY TO PALE GREEN; UPPER FINE TO UPPER MEDIUM, OCCASIONALLY LOWER COARSE; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUND, WITH OCCASIONALLY WELL ROUNDED AND ANGULAR; PREDOMINANTLY HIGH SPHEROIDAL SPHERICITY; APPROXIMATELY HALF SAMPLE LOOSE UNCONSOLIDATED GRAINS WITH BALANCE BEING EASILY FRIABLE TO FRIABLE; PREDOMINANTLY GRAIN SUPPORT WITH SOME CLAY MATRIX SUPPORT; CRUMBLY TO SUB-BRITTLE; IRREGULAR TO SUB-BLOCKY; TABULAR TO WEDGELIKE CUTTINGS HABIT; THICK BEDDED WITH THIN CALCITE CEMENTED SANDSTONE, HARD TO VERY HARD; POOR TO NO VISIBLE POROSITY OVERALL. 1400' TUFFACEOUS CLAYSTONE LIGHT GRAY TO MEDIUM LIGHT GRAY TO PALE YELLOWISH BROWN; SOFT TO MODERATELY FIRM; SOFT RETURNS VARY BETWEEN MODERATE COHESIVE TO HIGH COHESIVE AND SLIGHTLY ADHESIVE TO HIGHLY'ADHESIVE; MUSHY TO PASTY; IRREGULAR TO SUB-BLOCKY FOR CONSOLIDATED CUTTINGS; SMOOTH TO GRITTY TEXTURE; THICK BEDDED WITH THIN INTERBEDS OF CARBONACEOUS SHALES AND SUB-BITUMINOUS COALS. 1460' SAND MEDIUM DARK GRAY TO MEDIUM LIGHT GRAY OVERALL, INDIVIDUAL GRAINS RANGE FROM WHITE TRANSLUCENT TO TRANSPARENT, MEDUIM DARK GRAY TO DARK GRAY, PINKISH GRAY TO PALE GREEN; UPPER VERY FINE TO UPPER MEDIUM GRAINED; FAIR TO WELL SORTED; SUBROUNDED TO SUBANGULAR WITH OCCASIONALLY ANG; MODERATE TO HIGH SPHER-OIDAL SPHERICITY;PREDOMINANTLY UNCONSOLIDATED WITH OCCASIONALLY CUTTINGSOF HIGH. CALCCEMENTEDSANDSTONE; LOOSE GRAINS GRAIN SUPPORTED WITH SME MATRIX SUPPORT; 40% QUARTZ, 30% CHERT, 30% VARIOUS LITHIC/MAFIC FRAGMENTS; FAIR TO POOR EST VISIBLE POROSITY. 1550' TUFFACEOUS CLAYSTONE VERY LIGHT GRAY TO MEDUIM LIGHT GRAY, GRAYISH WHITE AND OCCASIONALLY LIGHT BROWNISH GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SLIGHTLY FIRM; COMMON AS SOUPY, PASTY AND MUSHY WELL HYDRATED MATERIAL IN SAMPLES WITH MODERATE TO HIGH ADHESION AND LOW TO MODERATE COHESION; VERY SMOOTH AND SLICK TO FINELY SILTY AND SANDY; GENERALLY DULL WITH SCATTERED MICROSPARKLES FROM SUSPENDED REFLECTIVE DETRITAL MATERIAL; MOSTLY NON CALCAREOUS BUT OCCASIONALLY PINPOINT REACTION ASSOCIATED WITH LITHIC DETRITUS; GENERALLY APPEARS AS HIGHLY SMECTITIC VOLCANICLASTIC CLAY WITH STRONG HYDRATION CHARACTERISTICS; NOTE BROWNISH VARIETY TENDS TO BE FAIRLY HIGH IN OVERALL CARBONACEOUS COMPOSITION WITH FAIRLY COMMON LIGNITIC MATERIAL AND BITUMINOUS FLAKES. 1640' CARBONACEOUS SHALE PALE BROWN TO DUSKY BROWN AND YELLOWISH BROWN WITH COMMON BROWNISH BLACK MOTTLING ASSOCIATED WITH LIGNITIC AND BITUMINOUS MATERIAL; SOFT AND CRUMBLY TO MODERATE HARD AND WELL INDURATED; DULL AND EARTHY WITH DISSEMINATED MICROSPARKLES TO OCCASIONALLY VAGUELY SUBRESINOUS AND SILKY WHEN WET; MODERATE SMOOTH TO VERY FINELY SILTY AND GRAINY; NON TO OCCASIONALLY WEAK DISSEMINATED CALCITE; GRADATIONAL TO CARBONACEOUS SILTSTONE. 1700' SAND OVERALL VERY LIGHT GRAY TO MEDUIM LIGHT GRAY AND MEDUIM L. IGHT GRAY TO MEDUIM DARK GRAY WHERE CONSOLIDATED AS CALC/SILIC SANDSTONE; LOWER VERY FINE TO UPPER MEDUIM; MODERATE TO POORLY SORTED; ANGULAR TO SUBROUNDED; MODERATE SPHERICITY; SUSPECTED TO BE MOSTLY AS FREE SAND GRAINS SUPPORTED BY HIGHLY SMECTITIC CLAY MATRIX; MOSTLY TRANSLUCENT, CLEAR AND MILKY WHITE QUARTZ WITH SCATTERED DARK GRAY TO BLACK DETRITAL GRAINS AND SCATTERED OPAQUE LIGHT GRAY TO CHALKY WHITE FELDSPARS;MINOR PALE REDDISH BROWN STAINING ASSOCIATED WITH CARBONACEOUS MATERIAL; LITHIC COMPOSITION IS DOMINANTLY MAFIC-RICH IGNEOUS GRAINS. TOP TYONEK AT 1753' 1770' COAL DUSKY BROWN TO BROWNISH BLACK AND BLACK WITH OCCASIONALLY GRAYISH BLACK HUES; SOFT TO MODERATE FIRM; BRITTLE, SPLINTERY, BLOCKY, TABULAR, IRREGULAR WEDGELIKE AND CONCHOIDAL CUTTINGS WITH COMMON BIRDSEYE TEXT; SMOOTH TO MATTE AND OCCASIONALLY GRAINY; GENERALLY SATINY AND MODERATE SHINY TO OCCASIONALLY MODERATE DULL; APPEARS MOSTLY AS SUBBITUMINOUS TO BITUMINOUS AND OCCASIONALLY LIGNITIC WHERE SILTY AND CLAYEY. 1830' SAND VERY LIGHT GRAY TO LIGHT GRAY WITH MEDUIM LIGHT GRAY TO VAGUELY BLUISH GRAY HUES; UP FINE TO LOW COARSE WITH OCCASIONALLY UP COARSE TO GRANULES OF 3-4mm; MOSTLY UNCONSOLIDATED BUT OCCASIONALLY VERY WELL CEMENTED; FAIR TO LOCALLY WELL SORTED; SUBROUND TO SUBANGULAR; MODERATE TO HIGH SPHEROIDAL SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED WITH SOME SMECTITIC CLAY MATRIX SUPPORT INFERRED; INDIVIDUAL GRAINS MOSTLY QUARTZ WITH ABUNDANT LITHIC/MAFIC FRAGMENTS DOMINATED BY CHERTS AND ARGILLITE. 1880' TUFFACEOUS CLAYSTONE VERY LIGHT GRAY TO LIGHT GRAY, OCCASIONALLY LIGHT BROWNISH GRAY; PREDOMINANTLY VERY SOFT TO SOFT AMORPHOUS CLAYBALLS, OCCASIONALLY SOFT TO SLIGHTLY FIRM; CRUMBLY SUB-BLOCKY CUTTINGS; SOFT CLAYS VARY IN DEGREE OF ADHESION AND COHESION TENDING IN THE MODERATE TO HIGH RANGE; HYDRATES READILY AFTER WASHED AND DRIED. 1930' COAL GRAYISH BLACK-TO-BLACK, OCCASIONALLY BROWNISH BLACK TO OLIVE BLACK; MODERATELY FIRM TO HARD; SUB-BRITTLE TO BRITTLE; PREDOMINANTLY BLOCKY TO PLANAR WITH ABUNDANT CONCHOIDAL TO SPLINTERY HABIT; DULL LUSTER, OCCASIONALLY VITREOUS; MATTE TEXTURE ; BITUMINOUS TO SUB-BITUMINOUS. 2030' SAND LIGHT GRAY TO VERY LIGHT GRAY, WITH BROWNISH HUES FROM CLAY IN SAMPLE; UPPER FINE TO UPPER MEDUIM GRAINED, OCCASIONALLY COARSE; PREDOMINANTLY UNCONSOLIDATED QUARTZ WITH ABUNDANT DETRITAL LITHIC/ MAFIC FRAGMENTS; FAIR SORTING OVERALL; SUBROUND TO SUBANGULAR; HIGH TO MODERATE SPHEROIDAL SPHERICITY; OCCASIONALLY CUTTINGS WELL CEMENTED WITH CALCAREOUS CEMENT, HARD TO VERY HARD, BRITTLE, IRREGULAR TO BLOCKY APPEARS AS THIN TO VERY THIN BEDDING. 2090' TUFFACEOUS CLAYICLAYSTONE LIGHT GRAY TO LIGHT MEDUIM GRAY GRADING TO BROWNISH GRAY HUES LOCALLY; VERY SOFT TO SOFT AMORPHOUS CLAYBALLS, OCCASIONALLY SLIGHTLY FIRM; HIGH TO MODERATE ADHESION; HIGH COHESION; MICROMICACOUS IN PART. 2180' SAND AND CONGLOMERATIC SAND MEDUIM LIGHT GRAY TO MEDUIM GRAY AND OCCASIONALLY BROWNISH GRAY TO PALE BROWN WHERE GRADATIONAL TO MUDSTONE; UPPER FINE TO UPPER COARSE WITH SCATTERED UPPER COARSE TO SMALL PEBBLES OF 3-5mm +; POOR TO MODERATELY SORTED; ANGULAR TO SUBROUNDED WITH OCCASIONAL WELL ROUNDED UPPER VERY COARSE THROUGH PEBBLE CLASTS; MODERATE TO HIGH SPHERICITY; UNCONSOLIDATED WITH OCCASIONALLY THIN, HARD VERY WELL CEMENTED CALCAREOUS INTERVALS AS REFLECTED BY SLOW ROP'S; 30 TO 50% l0 TRANSLUCENT, CLEAR AND MILKY WHITE QUARTZ; 20 TO 40% LITHIC FRAGMENTS INCLUDING DETRITAL COAL, PALE YELLOW BROWN TUFF, DARK GRAY TO BLACK UNDIFFERENTIATED ALTERED IGNEOUS LITHS, PALE GREEN LOW GRADE UNDIFFERENTIATED METAMORPHIC; 5-10% GRAY TO WHITE FELDSPAR; 5-10% CHERT; <5% BIOTITE, MUSC, MAFIC; VARIOIUS SMECTITIC MATRIX CLAY, GRAIN AND MATRIX SUPORTED. 2290' SAND/CONGLOMERATE MEDUIM LIGHT GRAY TO VERY LIGHT GRAY TO LIGHT BROWNISH GRAY DEPENDING ON WASHOUT OF CLAYS AND MUD SOLIDS; UPPER FINE TO UPPER MEDUIM PREDOMINANTLY, WITH ABUNDANT GRAINS RANGING THROUGH COARSE TO BIT BROKEN PEBBLE SIZE, FREQUENTLY OF COARSE GRAINS INCREASING WITH DEPTH; OVERALL FAIR TO POOR SORTED, LOCALLY WELL TO VERY WELL SORTED; UNBROKEN GRAINS SUBROUND TO SUBANGULAR; HIGH TO MODERATE SPHEROIDAL SPHERICITY; PREDOMINANTLY LOOSE QUARTZ THROUGHOUT WITH VARYING AMOUNTS OF LITHIC/MAFIC FRAGMENTS, AND RARE APPARENT DETRITAL COAL FRAGMENTS; VARYING AMOUNTS OF SMECTITIC CLAYS IN SAMPLES INFERRED AS MATRIX; GRAIN AND MATRIX SUPPORT INFERRED. 2330' COAL GRAYISH BLACK TO BLACK; FIRM TO MODERATELY HARD; BRITTLE TO SUB-BRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONALLY CONCHOIDAL; TABULAR TO WEDGELIKE CUTTINGS HABIT;PREDOMINANTLY DULL LUSTER, OCCASIONALLY SHINY; SMOOTH TO MATTE TEXTURE APPEARSPREDOMINANTLY BITUMINOUS WITH OCCASIONALLY SUB-' BITUMINOUS;SLIGHTLYTO MODERATE BUBBLING IN FRESH WET SAMPLE. 2420' =, TUFFACEOUS CLAYSTONE LIGHT BROWNISH GRAY TO LIGHT OLIVE GRAY; VERY SOFT TO SOFT AMORPHOUS CLAYBALLS; MODERATE COHESION; HIGH TO MODERATE ADHESION; CURDY TO CLOTTED' CONSISTENCY; DULL LUSTER; CLAYEY TO SILTY TEXTURE ;SLIGHTLY CALCAREOUS. 2450' COAL DARK BROWNISH BLACK TO BLACK WITH OCCASIONALLY DARK GRAYISH BLACK HUE; SOFT TO VERY FIRM AND MODERATELY HARD; CRUMBLY WHERE CLAY RICH AND GRADATIONAL TO CARBONACEOUS SHALE/ CARBONACEOUS MUDSTONE BUT MOSTLY VERY BRITTLE, SPLINTERY, BLOCKY TO TABULAR, WEDGELIKE AND CONCH CUTTINGS; COMMON VISIBLE GAS BLEEDS; FAIRLY SMOOTH TO MATTE; SATINY AND SUBVITREOUS TO MODERATE DULL; NOTE OCCASIONALLY THIN VERY FINE GRAIN CALCITE AND CARBONACEOUS SANDSTONE INTERLAMINATED WITH COAL. 2530' SAND AND CONGLOMERATIC SAND OVERALL MEDUIM LIGHT GRAY TO MEDUIM GRAY WITH OCCASIONALLY PALE BROWN TO BROWNISH GRAY AND PALE GREENISH GRAY HUES; LOW FINE TO LOW COARSE, DOMINANTLY LOW FINE TO UP MEDUIM AND OCCASIONALLY UP COARSE TO SMALL PEBBLES OF 3-6MM+; APPEARS BIMODAL WITH OCCASIONALLY LAG OF INCREASED GRAIN SIZE COMPOSITIONS; ANGULAR TO SUBROUNDED AND PERIODICALLY WELL ROUNDED;' MODERATE TO POORLY SORTED; MODERATE TO MODERATE HIGH SPHERICITY; MOSTLY UNCONSOLIDATEDOL BUT OCCASIONALLY THINLY INTERBEDDED VERY WELL CEMENTED CALCAREOUS SANDSTONE; 50 TO 70% CLEAR, TRANSLUCENT AND MILKY QUARTZ; 5 TO 15% FELDSPAR; 20 TO 30% "LITHICS INCLUDING GRAY TO BLACK UNDIFFERENTIATED IGNEOUS GRAY TO REDDISH CHERTY SILICA, CHLORITE AND EPIDOTE ALTERED METAMORPHICS; <5% MAFICS TRACE RED ORANGE Fe SELVEGED FELDSPARS; SCATTERED CLEAR INCLUDED VOLCANIC QUARTZ GRAINS; OCCASION DETRITAL COAL AND LIGNITIC PLANT DEBRIS; UNCONSOLIDATED; APPEARS SUPPORTED BY LIGHT GRAY TO GRAYISH WHITE AND OCCASIONAL PALE BROWNISH GRAY HYDRATING SMECTITIC MATRIX CLAYS;MINOR CONSOLODATED GRAIN SUPPORTED CALCAREOUS SANDSTONE. 2640' TUFFACEOUS CLAYSTONE LIGHT GRAY TO MEDUIM LIGHT GRAY GENERALLY ASSOCIATED WITH SANDS AND PALE BROWN TO BROWNISH GRAY ASSOCIATED WITH CARB MATERIAL AND GRADES TO CARB MUDSTONE AND CARBONACEOUS SHALE; SOFT TO MODERATE FIRM; COMMON WELL HYDRTED MASS MATERIAL IN SAMPLES WITH MODERATE TO LOW COHESIVENESS AND MODERATE TO HIGH ADHESION; NON CALCAREOUS TO OCCASIONALLY WEAKLY CALCAREOUS. 2680' COAL GRAYISH BLACK TO BLACK; MODERATE FIRM TO SLIGHTLY HARD; CRUMBLY TO SUB-BRITTLE; IRREGULAR TO BLOCKY; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO WAXY LUSTER; MATTE TO SMOOTH TEXTURE , LOCALLY GRADES TO CARBONACEOUS SHALE. 2720' SAND/CONGLOMERATE MEDUIM LIGHT GRAY TO MEDUIM GRAY OVERALL, TRANSPARENT TO FROSTED WHITE TO DARK GRAY; OCCASIONAL FRAGMENTS LIGHT GREENISH GRAY TO LIGHT GREEN, PALE REDDISH BROWN TO MODERATE RED; PREDOMINANTLY LOWER FINE TO UPPER COARSE, ABUNDANT GRANULES AND BIT BROKEN PEBBLES IN EXCESS OF 5mm; VERY POOR TO POOR SORTING; PREDOMINANTLY ROUND WITH ABUNDANT ROUND CLASTS, OCCASIONALLY SUBANGULAR TO SUBROUND; HIGH SPHERICITY, OCCASIONALLY MODERATE;ABUNDANT VISIBLE IMPACT TO FROSTED SURFACE ABRASION ON MOST LARGER GRAINS;SLIGHT TRACE CALCITE CEMENTED SANDSTONE; SAMPLES 100% UNCONSOLIDATED; CONGLOMERATIC SAND/CONGLOMERATE; 30-40% QUARTZ, 20-30% UNDIFFERENTIATED CHERTS, 20-30% METALITHIC FRAGMENTS (NOTABLY ARGILLITE, PHYLLITE), BALANCE VARIOUS UNDIFFERENTIATED IGNEOUS FRAGMENTS; GRAIN SUPPORT INFERRED. 2820' COAL DUSKY BROWN TO GRAYISH BROWN, OCCASIONALLY GRAYISH BLACK; MODERATE FIRM TO MODERATE HARD;PREDOMINANTLY CRUMBLY TO SUB- BRITTLE, OCCASIONALLY BRITTLE IRREGULAR TO BLOCKY FRACTURE, OCCASIONALLY CONCHOIDAL TO SPLINTERY; TABULAR TO WEDGELIKE CUTTINGS HABIT; WAXY TO DULL LUSTER; MATTE TO SMOOTH TO SILTY TEXTURE ; MODERATE VISIBLE GAS BLEEDS; GRADATIONAL BETWEEN CLAYEY/SILTY CARBON-ACEOUS SHALE AND SUBBITUMINOUS TO BITUMINOUS COAL. 2910' TUFFACEOUS CLAYSTONE MEDUIM LIGHT GRAY TO MEDUIM GRAY AND OCCASIONALLY PALE BROWNISH GRAY TO PALE BROWN; SOFT TO MODERATE FIRM; DULL WITH OCCASIONALLY DISSEMINATED MICROSPARKLES; MODERATE SMOOTH TO FINELY SILTY AND GRITTY; APPEARS AS SOUPY, PASTY, CLUMPY, WELL HYDRATED MASS MATERIAL IN SAMPLES THAT COMMON IS STUDDED BY SUSPENDED SILT AND SAND GRAINS; DOMINANTLY NON CALCAREOUS WITH OCCASIONALLY WEAK TO MODERATE CALCAREOUS STREAKS ASSOCIATED WITH CALCAREOUS SANDSTONE; TRACE YELLOWISH BROWN TO MODERATE BROWN AND GRAYISH BROWN CALCAREOUS TUFF AT 2960'. 2980' CONGLOMERATIC SAND AND SANDSTONE OVERALL BROWNISH GRAY TO PALE BROWN AND MEDUIM LIGHT GRAY TO MEDUIM GRAY; NOTE DIVERSE COLOR AND GRAIN SIZE RANGE; UPPER FINE TO UPPER COARSE WITH COMMON UPPER VERY COARSE TO SMALL PEBBLES UP TO 6mm+; ANGULAR TO SUBROUNDED WITH FAIRLY COMMON WELL ROUNDED COARSE THROUGH PEBBLE SIZE CALSTS; 50 TO 70% CLEAR, TRANSLUCENT, MILKY, FROSTED AND CHATTERED QUARTZ; 20'30% LITHICS INCLUDING UNDIFFERENTIATED INT IGNEOUS TUFF, LOW GRADE GREEN METAMORPHIC, CHERTY SILICS AND DETRITAL COAL; 5 TO 10% FELDSPARS; <5% SERIClTE/CHLORITE/MUSC; <5% REDDISH ORANGE Fe STAINED GRAINS; <5% FREE MAFIC MINERALS; POOR TO MODERATE SORTED; LOW TO MODERATE SPHERICTY OF FINES AND MODERATE TO HIGH SPHERICITY OF COARSE TO PEBBLE; MOSTLY SUPPORTED BY SMECTITIC MATRIX CLAYS; DOMINANTLY AS UNCONSOLIDATEDO SANDS BUT OCCASIONALLY AS WELL CEMENTED CALCAREOUS SANDSTONE. 13 3100' COAL GRAYISH BROWN TO GRAYISH BLACK; MODERATE HARD TO MODERATE FIRM; BRITTLE TO SUB-BRITTLE, OCCASIONALLY CRUMBLY; IRREGULAR TO BLOCKY FRACTURE, OCCASIONALLY CONCHOIDAL; TABULAR TO WEDGELIKE CUTTINGS; DULL AND MATTE TO SILKY AND SUBVITREOUS; PREDOMINANTLY SMOOTH TEXTURE ; MODERATE SPARSE VISIBLE GAS BLEEDS IN FRESH WET SAMPLE; BITUMINOUS TO SUB-BITUMINOUS COAL INTERBEDDED WITH AND GRADING TO OCCASIONALLY THIN CARBONACEOUS SHALE. 3160' TUFFACEOUS CLAYICLAYSTONE LIGHT GRAY TO LIGHT MEDUIM GRAY, OCCASIONALLY PALE BROWNISH GRAY; PREDOMINANTLY VERY SOFT TO SOFT AMORPHOUS CLAYBALLS, OCCASIONALLY SLIGHTLY TO MODERATELY FIRM; MODERATE COHESIVE; MODERATE TO HIGH ADHESION; CURDY TO MUSHY, OCCASIONALLY PASTY; FIRMER CUTTINGS SUB-BLOCKY TO ROUNDED; DULL TO EARTHY LUSTER WITH DISPERSED MICROMICACEOUS SPARKLES; HIGHLY SMECTITIC WITH RAPID HYDRATION IN FRESH H20. 3210' CALCAREOUS TUFFACEOUS SILTY SANDSTONE MEDUIM LIGHT GRAY TO MEDUIM GRAY AND PALE BROWN TO BROWNISH GRAY; LOWER VERY FINE TO LOWER COARSE WITH SCATTERED UPPER VERY COARSE TO PEBBLES OF 4- 5mm+, DIVERSE GRAIN SIZE RANGE WITH FINES TENDING TO BE MODERATE TO WELL SORTED AND COARSE FRACTION POORLY TO MODERATELY SORTED; ANGULAR TO SUBROUND AND OCCASIONALLY WELL ROUNDED; MODERATE TO OCCASIONALLY HIGH SPHERICITY OF LARGEST GRAINS; FIRM TO VERY HARD; VERY WELL CEMENTED BY CALCITE; TIGHT; GRAIN SUPPORTED; 50-70% TRANSLUCENT, CLEAR AND" MILKY QUARTZ; 10-15% PALE BROWN CALCAREOUS TUFF GRAINS; 20-30% UNDIFFERENTIATED METAMORPHIC AND IGNEOUS LITHICS; 5-10% FELDSPARS; <5% MICA AND MAFIC GRAINS. 3280' SAND MEDUIM GRAY TO MEDUIM LIGHT GRAY; MOSTLY LOW MEDUIM TO LOW COARSE WITH SCATTERED UPPER COARSE AND OCCASIONALLY SMALL GRANULES AND EBBLES OF 3-5mm+; MODERATE WELL SORTED; ANGULAR TO SUBROUNDED WITH WELL RNDING OF SOME VERY LARGE GRAINS; MODERATE TO LOW AND MODERATE HIGH AS VERY COARSE+; OVERALL APPEARS CLEAN WITH MOST SMECTITIC MATRIX CLAY WASHING OUT OF SAMPLES WITH LITTLE EFFORT; GRADED FINING UPWARED SEQUENCE; 50-70% CLEAR, TRANSLUCENT, FROST, PITTED AND MILKY QUARTZ; 30-50% LITHIC INCLUDING: BLACK CHERTY ARGILLITE, BASALT, RED-GREEN ALTERED RHYOLITE/RHYODAClTE, DARK GRAY TO GRAYISH WHITE MOTTLED DIORITE/TONALITE, YELLOW GREEN-WHITE EPIDOTIZED APLITE AND BLACK DETRITAL COAL; 5-10% FELDSPAR; <5% PALE 14 GREEN CHLORITE AND COLORLESS CHLORITE /SERICITE; <5% FREE MAFIC GRAINS; <5% REDDISH ORANGE Fe STAINED GRAINS/SELVEGED FELDSPAR. 3390' TUFFACEOUS MUDSTONE LIGHT GRAY TO MEDUIM LIGHT GRAY AND BROWNISH GRAY TO PALE BROWN; SOFT TO MODERATE FIRM; MOSTLY AS VERY WELL HYDRATED SOUPY TO PASTY MASSES IN SAMPLE WITH LOW TO MODERATE COHESION AND MODERATE TO HIGH ADHESION; COMMON SUSPENDED SILT AND SAND GRAINS; DULL WITH SCATTERED MICROSPARKLES; HIGHLY SMECTITIC AND GRADES TO FRIABLE ARGILLACEOUS SANDSTONE. 3430' COAL GRAYISH BLACK TO BLACK, OCCASIONALLY GRAYISH BROWN; HARD TO MODERATE HARD, OCCASIONALLY MODERATE FIRM; BRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE, OCCASIONALLY CONCHOIDAL; TABULAR TO WEDGE-LIKE CUTTINGS HABIT; SMOOTH TEXTURE, OCCASIONALLY MATTE; DULL TO SILKY LUSTER; SPARSE VISIBLE GAS BLEEDS IN FRESH WET SAMPLE; PREDOMINANTLY BITUMINOUS TO SUBBITUMINOUS INTERBEDDED WITH OCCASIONALLY THIN CARBONACEOUS SHALES. 3510' TUFFACEOUS CLAYICLAYSTONE LIGHT MEDUIM GRAY TO PALE BROWNISH GRAY, OCCASIONALLY LIGHT GRAY TO VERY LIGHT GRAY;PREDOMINANTLY VERY SOFT TO SOFT AMORPHOUS CLAYBALLS, OCCASIONALLY SLIGHTLYTO MODERATE FIRM; FIRM CUTTINGS ROUNDED TO SUB-BLOCKY; CRUMBLY; MICROMICACEOUS IN PART; CLAYEY TO SILTY TO GRITTY; SOFT MATERIAL CONTAINS AND REFLECTS ASSOCIATED LITHS. 3590' COAL BLACK TO VERY DARK BROWNISH BLACK AND DUSKY BROWN WHERE SCORED BY SAMPLE PROBE; MOSTLY AS VERY FIRM BRITTLE, SPLINTERY, RIGID, TABULAR, BLOCKY, CLEATED, WEDGELIKE AND SUBCONCHOIDAL CUTTINGS WITH COMMON VISIBLE OUTGASSING; FAIRLY DULL AND MATTE TO SILKY AND SHINY; DOMINANTLY SMOOTH TO OCCASIONALLY FINELY GRAINY WHERE EARTHY AND LIGNITIC; MOSTLY SUBBITUMINOUS TO BITUMINOUS AND OCCASIONALLY LIGNITIC WHEN ASSOCIATED WITH CARBONACEOUS SHALE AND MUDSTONE;MINOR TRANSLUCENT REDDISH BROWN AMBER. 3650' GRANULE BEARING SAND LIGHT GRAY TO MEDUIM LIGHT GRAY AND BROWN GRAY; UPPER VERY FINE TO UPPER MEDUIM WITH SCATTERED COARSE THROUGH GRANULES OF 2-4mm; MOSTLY UNCONSOLIDATEDOLIDATED BUT OCCASIONALLY APPEARS AS VERY WELL CEMENTED CALCAREOUS SANDSTONE; MODERATE TO POORLY SORTED; ANGULAR TO SUBROUNDED AND OCCASIONALLY WELL ROUNDED COARSE TO GRANULE; MODERATE TO HIGH SPHERICITY; 60-70% CLEAR, TRANSLUCENT, FROSTED, PITTED AND MILKY QUARTZ; 20-30% LITHICS INCLUDING: PALE YELLOW BROWN TUFF, QUARTZITE, PALE GREEN UNDIFFERENTIATED METAMORPHIC AND DARK GRAY TO BLACK UNDIFFERENTIATED IGNEOUS LITHS; 5-10% GRAY TO WHITE FELDSPARS; <5% FREE MAFIC GRAINS; <5% COLORLESS TO GREEN CHLORITE/SERIClTE; <5% BROWN MICA; <5% RED BROWN TO REDDISH ORANGE FERRO-SILIC INCLUDING JASPER, Fe SELVEGED FELD AND POS PALAGONITE; OVERALL APPEARS CLEAN WITH MINOR AMOUNT OF LIGHT GRAY TO GRAY WHITE SMECTITIC MATRIX CLAY. 3760' COAL GRAYISH BLACK TO GRAYISH BROWN; HARD TO MODERATELY HARD, OCCASIONALLY MODERATE FIRM- BECOMING INCREASINGLY SO WITH DEPTH; BRITTLE TO SUB-BRITTLE; BLOCKY TO CONCHOIDAL FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; SPARSE VISIBLE GAS BLEEDS IN FRESH WET SAMPLE; SMOOTH TEXTURE ; CUTTINGS IN UPPER SECTION PREDOMINANTLY BITUMINOUS, BECOMING INCREASINGLY SUBBITUMINOUS TO LIGNITIC WITH DEPTH. 3810' TUFFACEOUS CLAYICLAYSTONE LIGHT MEDUIM GRAY TO MEDUIM GRAY, OCCASIONALLY PALE BROWNISH GRAY; PREDOMINANTLY VERY SOFT TO SOFT AMORPHOUS SHAKER-FORMED CLAYBALLS; OCCASIONALLY FIRM CUTTINGS IN SAMPLE; SUBBLOCKY TO IRREGULAR, ROUNDED IN RETURNS, CRUMBLY TO SUB-BRITTLE; MICROMICACEOUS IN PART, CLAYEY TO SILTY TEXTURE; SOFTER RETURNS HEAVILY CONTAMINATED WITH SAND, COAL, AND OTHER RETURNS. 3860' COAL GRAYISH BLACK TO GRAYISH BROWN, OCCASIONALLY BLACK; HARD TO MODERATELY HARD, OCCASIONALLY FIRM; BRITTLE TO SUB-BRITTLE TO CRUMBLY;. BLOCKY TO PLANAR TO CONCHOIDAL FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; SMOOTH TO MATTE TEXTURE ; DULL TO SATINY LUSTER; SPARSE TO NONE VISIBLE GAS BLEEDS IN FRESH WET SAMPLE; BITUMINOUS TO SUB-BITUMINOUS TO OCCASIONALLY LIGNITIC; OCCASIONALLY THIN INTERBEDS OF CARBONACEOUS SHALE. 3910' SANDSTONE LIGHT GRAY TO LIGHT MED'UIM GRAY; FIRM FRIABLE TO MODERATE HARD; CALCIC CEMENTD; GRAIN SUPPORTED WITH SOME CEMENT SUPPORT; IRREGULAR FRACTURE; FLAKY TO PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SUCROSICE TO ABRASVE TEXTURE ; INDIVIDUAL GRAINS 16 TRANSPARENT TO LIGHT GRAY; SUBANGULAR TO ANGULAR; MODERATE SPHERICITY; PREDOMINANTLY QUARTZ WITH LITHIC/MAFIC FRAGMENTS. 4000'. CALCAREOUS TUFF PALE YELLOWISH BROWN, PALE BROWN AND GRAYISH BROWN; HARD TO VERY HARD; APHANITIC AND CRYPTOCRYSTALLINE; MATTE AND VERY FINELY GRAINY TO MODERATE SMOOTH; DULL WITH SCATTERED MICRSPRKL AND SUBRESINOUS; DOLOMITIC TO VERY CALCAREOUS; MOSTLY AS DENSE, TOUGH, BLOCKY, RIGID, BRITTLE, ROUGH EDGED AND SUBCONCH CUTTINGS; GRADATIONAL TO CALCCAREOUS/DOLOMITIC VOLCANICLASTIC MUDSTONE/CLAYSTONE. 4050' PEBBLE/GRANULE BEARING SAND OVERALL MEDUIM GRAY TO MEDUIM LIGHT GRAY VARICOLORED WITH COM DARK GRAY AND BLACK CRYPTOCRYSTALLON CHERTY SILICEOUS LITHIC GRANULES AND PEBBLES; UPPER FINE TO UPPER VERY COARSE WITH COMMON GRANULES AND SCATTERED PEBBLES AND PEBBLE FRAGMENTS UP TO 9mm; POORLY SORTED; SUBANGULAR TO VERY WELL ROUNDED; MODERATE TO HIGH SPHERICITY; LITTLE APPARENT SMECTITIC MATRIX CLAY; 40 TO 60% CLEAR, TRANSLUCENT, MILKY AND FROST QUARTZ; 30 TO 50% LITHICS: BLACK, GRAY CHERT/SILICEOUS ARGLITE; GREEN TO DARK GREEN CHLORITE, SERP/JADEITE METAMORPHIC; GRAY, RED, WHITE, GREEN, BROWN ALTERED IGNEOUS; DETRITAL SILIC SANDSTONE AND COAL; 10 TO15% GY TO WHITE FELDSPAR; VERY RARE TRANSLUCENT PINK ROSE QUARTZ; TRACE PALE BROWN TO MODERATE BROWN SMECTITIC CARBONACEOUS SHALE. 4190' CALCAREOUS TUFF PALE YELLOWISH BROWN TO PALE YELLOWISH ORANGE; HARD, DENSE, BLOCKY, WEDGELIKE; ROUGH EDGED AND BRITTLE CUTTINGS; MATTE AND VERY FINELY GRAINY TO MODERATE SMOOTH; DULL WITH SCATTERED MICROSPARKLES AND OCCASIONAL VAGUE TRANSLUCENT; DISSEMINATED BLACK SPECS; SCATTERED MICRO-MICAS; OCCASIONALLY CARBONACEOUS DEBRIS; SUSPECT GRADATIONAL TO VOLCANICLASTIC MUDSTONE AND SILTSTONE; GENERALLY CRYPTOCRYSTALLINE AND APHANITIC. 4260' COAL GRAYISH BLACK TO OLIVE BLACK, OCCASIONALLY DUSKY BROWN; MODERATE HARD TO VERY FIRM; BRITTLE TO SUB-BRITTLE TO CRUMBLY; BLOCKY TO IR-REG FRACTURE, OCCASIONALLY CONCHOIDAL TO PLANAR; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO SATINY LUSTER; MATTE TO SMOOTH TEXTURE ;ABUNDANT TO SPARSE VISIBLE GAS BLEEDS IN FRESH WET SAMPLE; BITUMINOUS TO SUB-BITUMINOUS GRADING TO AND INTERBEDDED WITH LIGNITIC COALS AND CARBONACEOUS SHALES. ]7 4330' CARBONACEOUS SHALE/SILTSTONE BROWNISH GRAY TO BROWNISH BLACK; MODERATELY FIRM TOSLIGHTLY FIRM, OCCASIONALLY SLIGHTLY HARD; SUB- BRITTLE TO CRUMBLY; PLANAR FRACTURE; TABULAR TO PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; THIN BEDDED, GRADING TO AND INTERBEDDED WITH COAL- DECREASING WITH DEPTH. 4370' SAND/CONGLOMERATE MEDUIM LIGHT GRAY TO MEDUIM GRAY TO LIGHT GREENISH GRAY; UPPER FINE TO BIT BROKEN PEBBLE UP TO 10 mm; POOR TO MODERATE SORTED; SUBROUND TO ROUNDED, OCCASIONALLY SUBANGULAR; HIGH TO MODERATE SPHEROIDAL SPHERICITY OCCASIONALLY RARE DISCOIDAL SPHERICITY; INDIVIDUAL GRAINS TRANSPARENT TO WHITE TRANSLUCENT, MEDUIM GRAY TO DARK GREENISH GRAY, GREENISH GRAY TO LIGHT GREENISH GRAY; PREDOMINANTLY UNCONSOLIDATED QUARTZ WITH 20 TO 30% LITHIC/MAFIC FRAGMENTS; GRAIN SUPPORT INFERRED WITH POSSIBLE LOW AMOUNT CLAY MATRIX; GOOD VISIBLE EST POROSITY AND PERMEABILITY. 4440' CALCAREOUSlDOLOMITIC TUFF YELLOWISH GRAY TO LIGHT OLIVE BROWN; VERY HARD TO HARD; DENSE TO BRITTLE; IRREGULAR TO BLOCKY, WEDGELIKE TO TABULAR CUTTINGS HABIT; DULL TO WAXY LUSTER; MICROSUCROSIC TEXTURE ; MICROCRYSTALLINE TO CRYPTOCRYSTALLINE; GRADES BETWEEN DOLOMITE AND CALCAREOUS TUFF. 4530' COAL DARK BROWNISH BLACK TO BLACK WITH OCCASIONALLY DARK TRANSLUCENT REDDISH BROWN HUES; SOFT TO VERY FIRM; CRUMBLY, BRITTLE, SPLINTERY, SUBCONCHOIDAL, CLEATED, TABULAR, BLOCKY AND WEDGELIKE CUTTINGS WITH COMMON VISIBLE GAS BLEEDS IN WET SAMPLE; SHINY TO SILKY AND MATTE; GENERALLY SMOOTH TO OCCASIONALLY WOODY AND VERY FINELY SILTY; RARE TRANSLUCENT REDDISH BROWN TO YELLOWISH ORANGE AMBER; OCCASIONALLY DUSKY BROWN TO MODERATE BROWN AND BROWNISH BLACK CARBONACEOUS SHALE WITH COMMON CARBONACEOUS PLANT DEBRIS AND PARTINGS; MOSTLY SUBBITUMINOUS TO BITUMINOUS WITH MINOR LIGNITIC FRACTION; VERY RARE EUHEDRAL TO SUBHEDRAL CALCAREOUS FRACTURE FILL. 4620' SAND/CONGLOMERATE MEDUIM GRAY TO MEDUIM LIGHT GRAY OVERALL; LOWER FINE TO LOWER COARSE, WITH OCCASIONALLY BIT BROKEN PEBBLE 8 TO 14 mm OVERALL POOR TO MODERATE SORTED, QUARTZ GRAINS WELL SORTED CONSIDERED ALONE; SUBANGULAR TO SUBROUND, OCCASIONALLY ROUNDED; MODERATE TO HIGH SPHERICITY; GRAINS RANGE TRANSPARENT, VVHITE TRANSLUCENT, LIGHT GRAY; LIGHT GREENISH GRAY, MEDUIM REDDISH BROWN; 50% QUARTZ, 50% LITHIC/MAFIC FRAGMENTS; INFERRED GREEN SUPPORT WITH LITTLE CLAY MATRIX; INTERBEDDED WITH THIN VERY HARD TO HARD CALCITE AND SILICA CEMENTED SANDSTONE, CALCAREOUS TUFF, AND SILTSTONE. 4700' CARBONACEOUS SILTSTONE BROWNISH GRAY TO OLIVE GRAY, OCCASIONALLY MEDUIM GRAY; MODERATE FIRM TO SLIGHTLY HARD; CRUMBLY TO SUB-BRITTLE; IRREGULAR TO SUB-BLOCKY FRACTURE; TABULAR TO ELONGATED TO NODULAR CUTTINGS HABIT; EARTHY LUSTER, OCCASIONALLY SLIGHTLY SPARKLING/MICROMICACEOUS; SILTY TEXTURE; OCCASIONALLY CUTTINGS CONTAIN CALCAREOUS MATERIAL; GRADATIONAL BETWEEN SILTSTONE WITH VARYING AMOUNTS SUB-LIGNITIC MATERIAL AND CARBONACEOUS SHALE. 4750' COAL GRAYISH BLACK TO GRAYISH BROWN; OCCASIONALLY BLACK; HARD TO MODERATE HARD, OCCASIONALLY VERY FIRM; BRITTLE TO SUB-BRITTLE, OCCASIONALLY CRUMBLY; BLOCKY TO PLANAR TO SPLINTERY FRACTURE; TABULAR TO VVEDGELIKE CUTTINGS HABIT; MATTE TO SMOOTH; COMMON REDDISH BROWN STAINED ARGILACEOUS ANHEDRAL CALCAREOUS FRACTURE FILL. 4790' CARBONACEOUS SANDSTONE VERY LIGHT GRAY TO LIGHT GRAY WITH BLACK TO DARK BROWNISH BLACK CARBONACEOUS STREAKS; LOWER FINE TO LOWER MEDUIM; MODERATELY TO MODERATELY WELL SORTED; ANGULAR TO SUBROUNDED; MODERATE SPHERICITY; 70% CLEAR, TRANSLUCENT AND MILKY QUARTZ WITH 10 TO 15% CHALKY WHITE TO OPAQUE FELDSPARS AND 10 TO 20% DARK COLORED LITHICS; EASILY FRIABLE TO FIRM AND MODERATE CEMENTED CALCITE VARIABLE INTERGRANULAR SMECTITIC MATRIX CLAY WITH MODERATE TO LOW ESTIMATED VISIBLE POROSOTY; NOTE INFLUX OF FREE SAND GRAINS INCLUDING DISTINCTIVE ORANGE TO REDDISH-ORANGE PALAGONITE(?) IN SAMPLES FROM 4830' TO 4850'; TRACE STREAKS AND SECONDARY CALCAREOUS FRACTURE FILL. 4890' SAND LIGHT GRAY TO LIGHT MEDUIM GRAY OVERALL; INDIVIDUAL GRAINS DOMINANTLY TRANSLUCENT TO FROSTED WHITE TRANSLUCENT WITH RARE TO VERY RARE PALE GREENISH HUES, REDDISH HUES, DARK GRAYS; 95+% UNCONSOLIDATED QUARTZ; UPPER FINE TO UPPER VERY FINE, OCCASIONALLY LOW MEDUIM, RARE COARSE GRAINS; FAIR TO WELL SORTED; SUBROUNDED TO SUBANGULAR, OCCASIONALLY ROUND, OCCASIONALLY ANGULAR; HIGH TO MODERATE SPHERICITY OVERALL; GRAIN SUPPORTED INFERRED WITH SOME POSSIBLE TUFFACEOUS CLAY MATRIX SUPPORT; GRAIN SIZE, GRAIN ANGULARITY, LITHIC/MAFIC FRAG CONTENT INCREASE SLIGHTLY WITH DEPTH. 4960' CONGLOMERATE/SAND MEDUIM GRAY TO MEDUIM LIGHT GRAY; GRAIN SIZE RANGE FROM UPPER FINE TO BIT BROKEN PEBBLE (UP TO 8mm IN SAMPLE); SAND WELL SORTED, POOR SORTED OVERALL; FINER GRAINS TEND TOWARD SUBANGULAR TO SBROUND, CONGLOMERATE PREDOMINANTLY ROUND TO WELL ROUND EXCEPT WHERE BIT BROKEN; HIGH TO MODERATE SPHERICITY; 100% UNCONSOLIDATED; 50-60% QUARTZ, UNDIFFERENTIATED LITHIC/MAFIC. 20 Daily Activity Summary 09/12100 09113100 09114100 09/15/00 09116/00 09/17100 09118/00 DALLY ACTIVITY SUMMARY ANADARKO LONE CREEK #2 0'-92' Epoch on location, unit readied to commence logging at spud. Pick up bit #1, bit sub, and six 8" drill collars. Wait on starter parts for 398 pump. Pick up BHA and test surface lines. Replace seal on Iow torque valve and retest. Drill 17 %" hole to 92'. Drop double shot and survey on bottom. Pull out of hole and lay down 17 %" BHA. Pick up 12 ¼" BHA. 92'-245' Run in hole with 12 ¼" BHA and drill from 92' to 245'. Circulate hole clean and pull out of hole. Lay down 12 ¼" BHA and pick up bullnose and hole opener and attempt to get through rotary table. Modify 17 %" hole opener to go through table. Pick up BHA and modify 17 %" stabilizer to go through rotary table. Run in hole to 92' and break circulation. Drill from 92' to 103'. Open 12 ¼" hole to 17 %". Service rig. Open hole from 12 ¼" to 17 %" from 103' to 227' 245'-245' Open hole to 17 %" from 227' to 245'. Circulate hole clean. Make wiper run to conductor shoe and circulate hole clean. Trip out of hole and lay down 17 %" stabilizer and 17 %" hole opener. Rig up to run 13 3/8" casing. Attempt to make up casing. Lay down 2 joints and remove centralizer. Weld strap on shoe joint and shoe. Pick up and run in hole with 13 3/8" casing. Weld strap on first to second joint, second joint to floor, floor to third joint. Tag bottom at 244' and rig up cement head. Rig up and circulate casing volume. Rig up to cement unit and pressure test lines to 1500 psi. Drop bottom plug and load top plug. Pump 100 sacks lead cement at 12.8 ppg. Mix and pump 200 sacks tail cement at 15.7 ppg. Drop plug. Displace and bump plug with 2200 psi maximum. Wait on cement. 245'-245' Continue to wait on cement. Cut off 20" at 13 3/8" and lay down. Cut and dress 13 3/8" casing. Weld on wellhead and test to 1500 psi. Nipple up BOPs. 245'-245' Install diverter line. Nipple up bell nipple, trip tank fill lines and function test annular and knife valve. Chain down stack. Test annular and knife valve- draw down test with state witness. Pick up 12 ¼" bit and stabilizer and run in hole. Tag cement at 137'. Drill cement from 137' to 148'. Drill float collar. Drill cement from 151' to 191' 245'-505' Drill cement from 191' to 238'. Drill shoe and rat hole. Drill new hole from 245' to 270'. Circulate hole clean and trip out for 8 %" bit and new BHA. Pick up new BHA and run in hole. Drill from 270' to 505'. 505'-980' 09119100 09~20~00 09/21100 09~22~00 09~23~OO 09~24~00 09~25~00 Drill from 505' to 980'. Pull out of hole 5 joints. Hole tight with swab. Run in hole to bottom and circulate. Pull out of hole 6 stands. Run in hole. 980'11001'-1001' Circulate hole clean and trip out for hole opener. Lay down 8 %" stabilizers. Pick up hole opener and bullnose. Weld straps on bullnose hole opener. Trip in hole to 270'. Open hole to 12 ¼" from 270' to 880'. 1001'-1001' Open hole to 12 ¼" from 880' to 998'. Circulate hole clean and short trip to 13 3/8" shoe. Trip back to bottom, circulate and condition mud and spot pill. Pull out of hole to log. Lay down 8" drill collars, 12 ¼" stabilizers, and 12 ¼" hole opener with bullnose. Rig up wireline and make first run with array induction and neutron density. Make second run with dipmeter. Rig down wireline and rig up stabbing board and equipment to run 9 5/8" casing. Start to run 9 5/8" casing. 1001'-1001' Cut straps and lay down float collar and two joints 9 5/8" casing. Retrieve wear bushing. Run shoe, two joints 9 5/8", and float collar. Weld straps as needed. Run 9 5/8" casing. Pick up cement head and circulate casing volume. Cement 9 5/8" casing. Washout BOP to casing head. Center casing and rig up vent line from annular. Nipple down diverter line, puncture nipple, flowline, trip tank return, and hole fill up line. 1001'-1001' Continue to nipple down from 9 5/8" casing. 1001'-1001' Make up Koomey lines. Nipple up bell nipple, flow line, and trip tank fill line. Clean mud pit. Mix up PHPA mud. Hook up hole fill lines. Test choke manifold, top drive, safety and mud saver valves. Rig up and test BOPs and surface lines. Start to rig down test equipment. 1001'-1018' Break out and lay down test plug, cross-overs, 8" drill collars, and handling tools. Run in hole with 8 %" bit and tag cement at 886'. Wash to 906' and circulate hole clean for test. Weight up mud to 10.1 ppg. Test 9 5/8" to float collar at 1500 psi. Drill float equipment and drill cement from 910' to 964'. Test 9 5/8" casing at 1500 psi. Drill from 964' to 1001' and 17 feet of new formation to 1018'. Circulate and condition mud for leak-off test. Pull out of hole from 1018' to 992' and circulate. Make up and pump dry job. Pull out hole and lay down jars. Calibrate new BHA and pick up 3 drill collars. Run in hole with new BHA. 1018'-1085' Trip out and install teledrift and trip in hole to 998'. Clean pits and weight up new mud to 10.5 ppg. Change out pump to 6" liners. Wash from 998' to 1018' - 5 feet of hole fill. Circulate and displace annulus with new mud. Drill from 1018' to 1085'. 22 09~26~00 09127/00 09~28~00 09~29~00 09~30~00 10/01100 10102100 10/03100 10/04100 1085'-1604' Drill from 1085' to 1604'. 1604'-1981' Drill from 1604' to 1981'. Circulate bottoms up and pump pill and dry job. Pump survey and pull out of hole for short trip from 1981' to 1667'. Get 20 to 30 Klbs over pull in tight hole. Go in hole to 1981' and make up top drive. Circulate bottoms up and get back 670 units of gas with mud cut to 9.9 ppg from 10.5 ppg. Pump high viscosity pill and pull out of hole back reaming. 1981'-2163' Continue to pull out of hole and back ream. Clean clay and wall cake out of flowline. Retrieve survey and run in hole (ream tight spot at 1621'). Ream 60 feet to bottom. Drill from 1981' to 2013' and circulate bottoms up. Spot high viscosity pill on bottom. Run wireline survey at 1981'. Change out shaker screens. Drill from 2113' to 2163' and circulate for bit trip. Pull out of hole for bit #6. Back ream from 2163' to 1290'. 2163'-2475' Pull out of hole and back ream from 1290' to 530'. Swab hole in casing. Mix pill and work ball off. Continue to pull out of hole. Change out bit. Break down and clean teledrift. Run in hole and wash 40 feet to bottom. Drill from 2163' to 2266'. Service rig. Drill from 2266' to 2282' and circulate. Work on generator. Drill from 2282' to 2475'. 2475'-2899' Drill from 2475' to 2676'. Pump sweep and circulate bottoms up. Back ream out to 2079' for wiper trip. Run in hole. Drill from 2676' to 2899'. 2899'-3218' Drill from 2899' to 3116'. Circulate bottoms up for trip. Pull out of hole from 3116' to 2360'. Go in hole to 3116'. Circulate bottoms up, 35 units of gas at bottoms up. Drill from 3116' to 3218'. 3218'-3575' Drill from 3218' to 3525'. Circulate high viscosity pill for wiper trip. Pull out of hole from 3525' to 3210'. Pull 40 Klbs over weight. Circulate bottoms up. Drill from 3525' to 3575'. 3575'- 4015' Drill from 3575' to 4015'. 4015'-4136' Drill from 4015' to 4136'. Perform pump weighted sweep and circulate bottoms up. Pull out of hole - tight at 4032'. Back ream and pump out of hole to 3842'. Tight hole, lose circulation. Run in hole to bottom. Mix and pump 30 bbl L CM pill at 20 lbs per gallon and spot on bottom. Circulate spot LCM. Pull out of hole from 4136' to 3366'. Circulate to clean hole. Back ream and pull out of hole from 3366' to 2930'. 3.3 10105100 10106/00 10107/00 10108/00 10109100 4136'- 4136' Pull out of hole from 2930' to 9 5~8" shoe (990'). Circulate bottoms up and monitor well for 10 minutes. Continue to pull out of hole with BHA. Stand back heavy weight drill pipe, lay down jars, and stand back drill collars. Clear floor and pull wear bushing. Rig up to test BOP equipment. Test BOPs and surface lines. Pick up new bit, watermelon mill stabilizer, crossover, and jars. Go in hole to shoe. Cut and slip 70 feet of drill line. Go in hole to 4136' and ream from 3939' to 4136'. 4136' -4517' Drill from 4136' to 4517'. 4517' - 4787' Drill from 4517' to 4606'. Shod trip from 4606' to 4126'. Backream from 4606' to 4126'. Break circulation and pump sweep around. Drill from 4606' to 4787'. 4787' - 5000' Drill from 4787' to 4915'. Work on shale shakers. Drill from 4915' to 5000'. TD at 5000' MD at 3:40PM 10/8/00. Circulate bottoms up. Wiper trip to shoe. Trip in, circulate and condition hole for electric logs. 5000" Circulate and condition hole, POOH for E-logs. logs. Rig up wireline, run electric 24 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE 9/15/00, TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 245 YESTERDAY 245 24 Hour Footage 0 EPOCH LOGO . PRESENT OPERATION= NIPPLE UP CASING INFORMATION 20" @ 94' 13.375"@ 245' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 fi/hr SURFACE TORQUE 0 @ 0 0 @ 0 0 0 amps WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KIbs ROTARYRPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL' MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS= CU'I-I'ING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 0 0 @ 0 0.0 AVG= PROPANE(C-3) 0 @ 0 0 @ 0 0.0 CURRENT BUTANE(C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY WAIT ON CEMENT, CUT OFF AND NIPPLE DOWN/UP Epoch Personel On Board= T. SMITH, S. HARNER Daily Cost $2300 Report by: S. HARNER file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000915.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE 9/16100, TIME 00:00:00 DAILY WELLSITE REPORT EPOCH LOGO ...... DEPTH 245 YESTERDAY 245 24 Hour Footage 0 PRESENT OPERATION= DRILL CEMENT CASING INFORMATION 20"@92' 13 3/8"@245' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 112" 245' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 1 0 @ 1 -1.$ 155.3 ftJhr SURFACE TORQUE 0 @ 1 0 @ 1 -1.$ amps WEIGHT ON BIT 0 @ 1 0 @ 1 -1.$ 4.0 Klbs ROTARYRPM 0 @ 1 0 @ 1 -1.$ RPM PUMP PRESSURE 0 @ 1 0 @ I -1.$ psi DRILLING MUD REPORT DEPTH: 245 MW 10.0 ViS 70 PV 22 YP 27 FL Gels 7/15/26 CL- 600 FC SOL 8 SD 1 OIL MBL 22 pH 8 Ca+ 0 MWD SUMMARY INTERVAL TOOLS TO CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS= NONE CUTTING GAS 0 @ 0 0 @ 0 0 WIPER GAS= NONE CHROMATOGRAPHY(ppm) SURVEY= NONE METHANE(C-I) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH= NONE ETHANE(C-2) 0 @ 0 0 @ 0 0 'AVG= NONE PROPANE(C-3) 0 @ 0 0 @ 0 0 CURRENT NONE BUTANE(C-4) 0 @ 0 0 @ 0 0 CURRENT BAOKGROUND/AVG0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY DRILL CEMENT DAILY ACTIVITY SUMMARY DRILL CEMENT Epoch Personel On Board: TIM SMITH/STEVE HARNER Daily Cost 2300.00 Report by: TIME SMITH J :\NTj xhexp\Cook-6DT\West-3 WL\Moq_Neph\Lone-EO9\Mudl-~7TP\20000916.htm 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE Sep 17. 2000 TIME 22:22:16 DAILY WELLSITE REPORT DEPTH 505 YESTERDAY 244 24 Hour Footage 261 EPocH LOGo PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 105.0 @ 345 8.0 @ 381 32.1 28.1 ft/hr SURFACE TORQUE 197 @ 439 180 @ 292 159.5 197.2 amps WEIGHT ON BIT 17 @ 346 0 @ 310 4.3 3.8 Klbs ROTARY RPM 0 @ 477 0 @ 477 0.0 0 RPM PUMP PRESSURE 555 @ 294 153 @ 299 412.7 555 psi DRILLING MUD REPORT DEPTH: MW ViS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 36 @ 434 0 @ 430 5.2 TRIP GAS= CUTTING GAS 0 @ 477 0 @ 477 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 10043 @ 452 4 @ 336 1205.0 CONNECTION GAS HIGH= ETHANE(C-2) 10066 @ 452 10066 @ 477 993.6 AVG= PROPANE(C-3) 10089 @ 452 10089 @ 477 995.9 CURRENT BUTANE(C-4) 0 @ 477 0 @ 477 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 477 0 @ 477 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Epoch Personel On Board= T SMITH/S HARNER Daily Cost 2300.00 Report by: T SMITH file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000917.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE Sep 18, 2000 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 970 YESTERDAY 508 24 Hour Footage 462 EPOCH LOG©" PRESENT OPERATION= POOH CASING INFORMATION 20"@92' 13 3/8"@244' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH · LOW AVERAGE CURRENT AVG RATE OF PENETRATION 513.2 @ 661 5.1 @ 589 53.5 36.3 fi/hr SURFACE TORQUE 207 @ 961 192 @ 867 200.9 201.2 amps WEIGHT ON BIT 35 @ 657 0 @ 961 11.1 5.2 Klbs ROTARY RPM 0 @ 970 0 @ 970 0.0 0 RPM PUMP PRESSURE 555 @ 508 555 @ 970 556.2 555 psi DRILLING MUD REPORT DEPTH: 970 MW 10.2 VIS 41 PV 11 YP 9 FL 13 Gels 17/30/45 CL- 300 FC 3 SOL 10 SD 1 OIL 0 MBL 16 pH 10.5 Ca+ 0 MWD SUMMARY INTERVAL TOOLS TO CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 130 @ 823 I @ 956 19.5 TRIP GAS= N/A CUTTING GAS 0 @ 970 0 @ 970 0.0 WIPER GAS= 13 CHROMATOGRAPHY(ppm) SURVEY= N/A METHANE(C-I) 26242 @ 622 235 @ 956 4053.6 CONNECTION GAS HIGH= NONE ETHANE(C-2) 0 @ 970 0 @ 970 0.0 AVG=NONE PROPANE(C-3) 0 @ 970 0 @ 970 0.0 CURRENT NONE BUTANE(C-4) 0 @ 970 0 @ 970 0.0 CURRENT BACKGROUND/AVG N/A PENTANE(C-5) 0 @ 970 0 @ 970 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAySTONE; COAL/CARB MATL; SAND/SANDSTONE PRESENT LITHOLOGY 10% CALC TUFF; 20% COAL; 20% SAND; 10% SANDSTONE; 40 TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY Epoch Personel On Board= 4 Daily Cost 2300.00 Report by: T SMITH file://J:\NTjxhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000918.ht 10/25/00 Daily Report Page 1 of l Anadarko Lone Creek #2 REPORT FOR DATE Sep 19,2000 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 1001 YESTERDAY 1001 24 Hour Footage 0 !';'1 EPOCH LOGO PRESENT OPERATION= Opening Hole CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 611.1 @ 529 2.5 @ 349 68.8 12.3 ft/hr SURFACE TORQUE 205 @ 879 179 @ 382 182.7 205.2 amps WEIGHT ON BIT 32 @ 382 0 @ 866 6.0 0.0 Klbs ROTARY RPM 0 @ 879 0 @ 679 0.0 0 RPM PUMP PRESSURE 555 @ 323 555 @ 879 518.2 555 psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 11 @ 829 0 @ 589 1.7 TRIP GAS= CU'I-rlNG GAS 0 @ 879 0 @ 879 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 10043 @ 862 48 @ 350 654.2 CONNECTION GAS HIGH= ETHANE(C-2) 10066 @ 862 10066 @ 879 308.1 AVG= PROPANE(C-3) 10089 @ 862 10089 @ 879 308.8 CURRENT BUTANE(C-4) 0 @ 879 0 @ 879 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 879 0 @ 879 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Opening Hole. Note depth corr f/970' to 1001' after pipe strap. Drilling and gas data for HO Epoch Personel On Board= Daily Cost Report by: S. Harner ~~e://J:\NTjxhex~\C~~k~n~et\WestRegi~na~\M~q-Neph\L~neCreek2\Mud~~g...\200009~9.ht ' 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE Sep 20, 2000 TIME 23:00:08 DAILY WELLSITE REPORT EPocH LOG© DEPTH 1001 YESTERDAY 884 24 Hour Footage 117 PRESENT OPERATION= RUN CASING CASING INFORMATION 20" @ 92' 13 3/8" @ 245' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN' JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 136.5 @ 898 4.0 @ 986 43.2 45.0 fi/hr SURFACE TORQUE 205 @ 956 193 @ 965 204.4 195.0 amps WEIGHT ON BIT 12 @ 965 0 @ 994 0.9 7.6 Klbs ROTARY RPM 0 @ 1001 0 @ 1001 0.0 0 RPM PUMP PRESSURE 555 @ 884 555 @ 1001 559.8 555 psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 10 @ 943 1 @ 911 4.1 TRIP GAS= CUTTING GAS 0 @ 1001 0 @ 1001 0.0 WIPER GAS= 30u CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 2633 @ 988 430 @ 911 963.4 CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 1001 0 @ 1001 0.0 AVG= PROPANE(C-3) 0 @ 1001 0 @ 1001 0.0 CURRENT BUTANE(C-4) 0 @ 1001 0 @ 1001 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1001 0 @ 1001 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENTLITHOLOGY DAILY ACTIVITY SUMMARY OPEN HOLE TO 1001',POOH, E-LOG, RUN 95/§"CASING Epoch Personel On Board= 2+ 1trainee Daily Cost $1425.00 Report by: T. SMITH file://J:\NTj xhexp\CookInlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000920.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE 9/21/00. TIME 24:00:00 DALLY WELLSITE REPORT f'~'l EPOCH LOGO , DEPTH 1001 YESTERDAY 1001 24 Hour Footage 0 PRESENT OPERATION= NIPPLING UP CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 1001 0 @ 1001 -1.$ ft/hr SURFACE TORQUE 0 @ 1001 0 @ 1001 -1.$ amps WEIGHT ON BIT 0 @ 1001 0 @ 1001 -1.$ Klbs ROTARY RPM 0 @ 1001 0 @ 1001 -1.$ RPM PUMP PRESSURE 0 @ 1001 0 @ 1001 -1.$ psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) 'HIGH LOW AVERAGE DITCH GAS 0 @ 1001 0 @ 1001 -1.$ TRIP GAS= CUTTING GAS 0 @ 1001 0 @ 1001 -1.$ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 0 @ 1001 0 @ 1001 -1.$ CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 1001 0 @ 1001 -1.$ AVG= PROPANE(C-3) 0 @ 1001 0 @ 1001 -1.$ CURRENT BUTANE(C-4) 0 @ 1001 0 @ 1001 -1.$ CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1001 0 @ 1001 -1.$ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RUN 9 5/8" CASING, CEMENT CASING, PREPARE TO NIPPLE UP Epoch Personel On Board= 2 + 1 trainee Daily Cost 1425.00 Report by: T. SMITH file://J:\NTjxhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000921 .ht 10/25/00 Daily Report Page 1 of l Lone Creek #2 REPORT FOR BOB WILEY DATE 9/22/00 TIME 24:00:00 DALLY WELLSITE REPORT DEPTH 1001 YESTERDAY 1001 24 Hour Footage 0 EPocH LoGO PRESENT OPERATION= NIPPLE UP CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW AVERAGE CURRENT AVG 0.0 @ 1001 0 @ 1001 N/A N/A fi/hr 0 @ 1001 0 @ 1001 N/A N/A amps 0 @ 1001 0 @ 1001 N/A N/A KIbs 0 @ 1001 0 @ 1001 N/A N/A RPM 0 @ 1001 0 @ 1001 N/A N/A psi DRILLING MUD REPORT MW VIS FC SOL DEPTH: PV YP FL Gels CL- SD OIL MBL pH Ca+ CCI MVVDSUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 1001 0 @ 1001 N/A TRIP GAS= CUTTING GAS 0 @ 1001 0 @ 1001 N/A WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 0 @ 1001 0 @ 1001 N/A CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 1001 0 @ ,1001 N/A AVG= PROPANE(C-3) 0 @ 1001 0 @ 1001 N/A CURRENT BUTANE(C-4) 0 @ 1001 0 @ 1001 N/A CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1001 0 @ 1001 N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY NIPPLE UP Epoch Personel On Board= 4+1trainee Daily Cost 1975.00 Report by: T. SMITH file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000922.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE 9/23/00, TIME 24:00:00 DALLY WELLSITE REPORT EPOCH 'LOGO DEPTH 1001 YESTERDAY 1001 24 Hour Footage 0 PRESENT OPERATION= L/DTEST EQUIPMENT CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 1001 0 @ 1001 NA ftJhr SURFACE TORQUE 0 @ 1001 0 @ 1001 NA amps WEIGHT ON BIT 0 @ 1001 0 @ 1001 NA Klbs ROTARY RPM 0 @ 1001 0 @ 1001 NA RPM PUMP PRESSURE 0 @ 1001 0 @ 1001 NA psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 1001 0 @ 1001 NA TRIP GAS= CUTTING GAS 0 @ 1001 0 @ 1001 NA WlPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 0 @ 1001 0 @ 1001 NA CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 1001 0 @ 1001 NA AVG= PROPANE(C-3) 0 @ 1001 0 @ 1001 NA . CURRENT BUTANE(C-4) 0 @ 1001 0 @ 1001 NA CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1001 0 @ 1001 NA HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY TEST BOPs AND LINES Epoch Personel On Board= 4+1TRAINEE Daily Cost 1975.00 Report by: T, SMITH file ://J :\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000923 .ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR BOB WILEY DATE Sep 24, 2000 TIME 24:00:00 DAILY WELLSITE REPORT 'EpocH LOGO DEPTH 1018 YESTERDAY 1001 24 Hour Footage 17 PRESENT OPERATION= MAKE NEW BHA CASING INFORMATION 20" @ 92' 13 3/8" @ 244' 9 5/8" @ 998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 357.1 @ 1002 10.9 @ 1013 42.7 22.0 ftJhr SURFACE TORQUE 197 @ 1003 194 ' @ 1006 207.2 194.3 amps WEIGHT ON BIT 8 @ 1006 4 @ 1003 7.4 7.8 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 17 @ 1006 1 @ 1013 5.5 TRIP GAS= NONE CUTTING GAS 0 @ 1018 0 @ 1018 0.0 WIPER GAS= N/A CHROMATOGRAPHY(ppm) SURVEY= N/A METHANE(C-I) 3066 @ 1006 417 @ 1013 1132.7 CONNECTION GAS HIGH= N/A ETHANE(C-2) 0 @ 1018 0 @ 1018 0.0 AVG= N/A PROPANE(C-3) 0 @ 1018 0 @ 1018 0.0 CURRENT N/A BUTANE(C-4) 0 @ 1018 0 @ 1018 0.0 CURRENT BACKGROUND/AVG N/A PENTANE(C-5) 0 @ 1018 0 @ 1018 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10-20% calcareous tuff; 30-40% tuffaceous claystone; 10-20% coal; 20-40% carbonaceous mat'l PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY Drill cement & shoe, drill 17' new formation, do LOT, POOH, M/U new BHA, RIH @ report time. Epoch Personel On Board= 4 Daily Cost $1975.00 Report by: T. SMITH file ://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000924.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Sep 25, 2000 TIME 24:00:00 DAILY WELLSITE REPORT DEPTH 1085 YESTERDAY 1018 24 Hour Footage 67 EPOCH LOGO · PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 75.3 @ 1024 8.6 @ 1059 44.3 21.9 ftJhr SURFACE TORQUE @ @ amps WEIGHT ON BIT 8 @ 1056 1 @ 1019 6.3 7.8 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 1020 MW 10.5 ViS 52 PV 11 YP 23 FL 8 Gels 9/11/11 CL- 100 FC 1 SOL 8 SD 0 OIL 0 MBL 0 pH 10 Ca+ 0 MWD SUMMARY INTERVAL TOOLS TO CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 34 @ 1065 0 @ 1035 7.3 TRIP GAS= NONE CUTTING GAS 0 @ 1068 0 @ 1068 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 7704 @ 1065 153 @ 1035 1559.3 CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 1068 0 @ 1068 0.0 AVG-- PROPANE(C-3) 0 @ 1068 0 @ 1068 0.0 CURRENT BUTANE(C-4) 0 @ 1068 0 @ 1068 0.0 CURRENT BACKGROUND/AVG 7 PENTANE(C-5) 0 @ 1068 0 @ 1068 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL/CALCAREOUS TUFF/TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE AND COAL DAILY ACTIVITY SUMMARY GET MUD TO 10.5 PPG, DRILL Epoch Personel On Board= 4 Daily Cost 1925.00 Report by: T. SMITH file ://J:\NTj xhexp\C'ooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000925 .ht 10/25/00 Daily Report Page 1 of l PETER LEACH Lone Creek #2 REPORT FOR DATE Sep 26, 2000 TIME 24:00:00 DALLY WELLSITE REPORT DEPTH 1604 YESTERDAY 1085 24 Hour Footage 519 r';7'-'EpoCH LOGO PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 147.9 @ 1386 2.3 @ 1220 38.7 29.4 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 18 @ 1318 1 @ 1397 8.1 10.9 Klbs ROTARY RPM 0 @ 1580 0 @ 1580 0.0 0 RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 1600 MW 10.5 VIS 54 PV 15 YP 25 FL 6.8 Gels 12-14-15 CL- 600 FC 1 SOL 10 SD 0.25 OIL 0 MBL 7.5 pH 8.5 Ca+ 20 MWD SUMMARY INTERVAL TOOLS TO CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 51 @ 1560 0 @ 1463 10.8 TRIP GAS= N/A CUTTING GAS 0 @ 1580 0 @ 1580 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 12140 @ 1560 112 @ 1463 2364.8 CONNECTION GAS HIGH= NONE ETHANE(C-2) 10066 @ 1577 10066 @ 1580 81.3 AVG= PROPANE(C-3) 10089 @ 1577 10089 @ 1580 81.5 CURRENT BUTANE(C-4) 0 @ 1580 0 @ 1580 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1580 0 @ 1580 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE/CLAYSTONE, SAND/SANDSTONE, CARB MATERAL PRESENT LITHOLOGY AS ABOVE DAILY ACTIVITY SUMMARY DRILL Epoch Personel On Board= 4 Daily Cost 1925.00 Report by: T. SMITH ~~e://J:\NTjxhexp\C~~k~n~et\WestRegi~na~\M~q-Neph\L~neCreek2\Mud~~g...\2~~~~926.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Sep 27,2000 TIME 24:00:00 DAILY WELLSITE REPORT EPOCH LOGO DEPTH 1981 YESTERDAY 1604 24 Hour Footage 377 PRESENT OPERATION= BACKREAM OUT CASING INFORMATION 20" @ 92' 13 3/8" @ 244' 9 5/8" @ 998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 99.1 @ 1815 3.1 @ 1838 35.0 27.1 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 22 @ 1971 0 @ 1816 9.2 14.0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 1981 MW 10.5 VIS 50 PV 13 YP 20 FL NA Gels 9-10-12 CL- 900 FC 1 SOL 10 SD 0.25 OIL MBL 10 pH 9.0 Ca+ 20 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 48 @ 1770 0 @ 1913 10.2 TRIP GAS= N/A CU'FI'ING GAS @ @ WIPER GAS= 670u CHROMATOGRAPHY(ppm) SURVEY= N/A METHANE(C-I) 17240 @ 1939 344 @ 1733 2398.4 CONNECTION GAS HIGH=2u ETHANE(C-2) 0 @ 1980 0 @ 1980 0.0 AVG= N/A PROPANE(C-3) 0 @ 1980 0 @ 1980 0.0 CURRENT NONE BUTANE(C-4) 0 @ 1980 0 @ 1980 0.0 CURRENT BACKGROUND/AVG 15u PENTANE(C-5) 0 @ 1980 0 @ 1980 0.0 HYDROCARBON SHOWS ~ INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE, SAND/SANDSTONE, COAL PRESENT LITHOLOGY 70% TUFFACEOUS CLAYSTONE, 20% TUFFACEOUS SlLTSTONE, 10% CALCIC SANDSTONE DAILY ACTIVITY DRILL TO 1981', ATTEMPT WIPER TRIP TO SHOE, TIGHT HOLE, GO BACK TO BO'II'OM, CIRCULATE OUT 670 UNITS SUMMARY GAS WITH MUD CUT TO 9.9 FROM 10.5, BACKREAM OUT. Epoch Personel On Board= 4 Daily Cost 1925.00 Report by: T. SMITH file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000927.ht 10/25/00 Daily Report Page 1 ot'l ANADARKO Lone Creek//2 REPORT FOR PETER LEACH DATE Sep 28, 2000 TIME 19:41:00 DAILY WELLSITE REPORT i~'l EPOCH LOGO . . DEPTH 2163 YESTERDAY 1986 24 Hour Footage 177 PRESENT OPERATION= BACKREAM/POOH CASING INFORMATION 20" @ 92' 13 3/8" @ 244'9 5~8" @ 998' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW 'AVERAGE CURRENT AVG RATE OF PENETRATION 77.0 @ 2058 3.1 @ 2142 24.3 12.2 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 21 @ 2056 3 @ 2101 10.8 5.3 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 2163 MW 10.5 VIS 48 PV 13 YP 25 FL 4.9 Gels 10/12/16 CL- 1100 FC 1 SOL 10.5 SD 0.25 OIL 0 MBL 11 pH 9.4 Ca+ 20 CCI MWD SUMMARY INTERVAL · TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 66 @ 2096 2 @ 2160 10.5 TRIP GAS= NONE CUTTING GAS @ @ WIPER GAS= N/A CHROMATOGRAPHY(ppm) SURVEY= NONE METHANE(C-I) 10043 @ 2161 401 @ 2158 2091.8 CONNECTION GASHIGH:NONE ETHANE(C-2) 0 @ 2163 0 @ 2163 0.0 AVG=0 PROPANE(C-3) 0 @ 2163 0 @ 2163 0.0 CURRENT NONE BUTANE(C-4) 0 @ 2163 0 @ 2163 0.0 CURRENT BACKGROUND/AVG 5u PENTANE(C-5) 0 @ 2163 0 @ 2163 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE/SILTSTONE; COAL; SAND/SANDSTONE PRESENT LITHOLOGY 10% SAND; 20% TUFFACEOUS SlLTSTONE; 70% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY DRILL TO 2163'; CIRCULATE B/U; BACKREAM OUT OF HOLE Epoch Personel On Board= 4 Daily Cost 1925.00 Report by: T. SMITH ~~e://J:\NTjxhexp\C~~k~n~et\WestRegi~na~\M~q-Neph\L~neCreek2\Mud~~g~~~\2~~~~928~ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Sep 29, 2000 TIME 00:00:15 DALLY WELLSITE REPORT DEPTH 2475 YESTERDAY 2163 24 Hour Footage 312 EPocH LOGO .... PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 66.6 @ 2362 4.1 @ 2300 31.5 21.5 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 25 @ 2272 0 @ 2395 12.4 11.8 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 2475 MW 10.5 VIS 48 PV 13 YP 18 FL 4.7 Gels 8-9-12 CL- 1200 FC 2 SOL 10.5 SD 0.25 OIL TR MBL 15 pH 9.5 Ca+ 20 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 175 @ 2363 0 @ 2277 23.5 TRIP GAS= 98 CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 34795 @ 2363 94 @ 2274 4909.2 CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 2475 0 @ 2475 0.0 AVG= PROPANE(C-3) 0 @ 2475 0 @ 2475 0.0 CURRENT BUTANE(C-4) 0 @ 2475 0 @ 2475 0.0 CURRENT BACKGROUND/AVG 90 PENTANE(C-5) 0 @ 2475 0 @ 2475 0.0 HYDROCARBON SHOWS MOST SIGNIF GAS IN COAL @ 2350' = 175 UNITS ( C-1 AND TRACE ONLY C-2) INTERVAL LITHOLOGY/RE MAR KS GAS DESCRI PTI ON LITHOLOGY TUFFACEOUS CLAYSTONE, CARBONACEOUS SHALE, COAL, SAND/SANDSTONE PRESENT LITHOLOGY CARBONACEOUS SHALE AND COAL W/OCC V THIN SANDSTONE LAMS DAILY ACTIVITY SUMMARY POH, TIH, DRILL AHEAD Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000929.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Sep 30, 2000 TIME 23:48:03 DAILY WELLSITE REPORT DEPTH 2899 YESTERDAY 2475 24 Hour Footage 424 EPOCH LoG© PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 87.0 @ 2643 2.6 @ 2874 34.7 13.1 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 31 @ 2561 2 @ 2738 18.9 19.2 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 2899 MW 10.5 VIS 48 PV 14 YP 20 FL 4.9 Gels 7~8~8 CL- 1100 FC 1 SOL 10.75 SD 0.25 OIL TR MBL 12.5 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS .145 @ 2572 3 @ 2558 22.6 TRIP GAS= CUTTING GAS @ @ WIPER GAS= 72 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 64576 @ 2572 401 @ 2875 5335.4 CONNECTION GASHIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 13/10 PENTANE(C-5) @ HYDROCARBON SHOWS MOST SIGNIF GAS IN COAL @ 2572 = 145u (C-1 WITH TRACE ONLY C-2 & C-3) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFF CLYST, CARB SHALE, COAL AND SAND W/OCC THIN TUFF PRESENT LITHOLOGY TUFF CLYST AND SAND DAILY ACTIVITY SUMMARY DRILL TO 2676 AND WIPE HOLE TO 2111. DRILL AHEAD Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20000930.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 01,2000 TIME 23:47:04 DAILY WELLSITE REPORT DEPTH 3218 YESTERDAY 2899 24 Hour Footage 319 i'~'l EPOCH 'LoGo PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 63.4 @ 3094 4.5 @ 3185 24.4 7.2 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 32 @ 2950 5 @ 3035 20.1 19.0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 3218 MW 10.5 ViS 50 PV 14 YP 22 FL 4.6 Gels 8/10/11 CL- 1100 FC 1 SOL 11 SD 0.25 OIL TR MBL 15.0 pH 9.6 Ca+ 20 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 50 @ 3094 1 @ 3195 9.2 TRIP GAS= CU-I-I'ING GAS @ @ WIPER GAS= 35 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 10629 @ 3094 147 @ 3195 1875.0 CONNECTION GAS HIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT 2 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 1 PENTANE(C-5) @ @ HYDROCARBON SHOWS MAX GAS @ 3094' = 50u (C-1 ONLY) IN COAL INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFF CLYST, CARB SHALE, COAL, SAND/CONGLOMERATE PRESENT LITHOLOGY TUFF AND SANDSTONE DAILY ACTIVITY SUMMARY DRILL TO 3116' AND WIPE HOLE, DRILL AHEAD. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file ://J :\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001001 .ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 02, 2000 TIME 23:48:24 DALLY WELLSITE REPORT DEPTH 3575 YESTERDAY 3218 24 Hour Footage 357 EPOCH LO® PRESENT OPEFLATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 62.0 @ 3302 2.8 @ 3219 25.9 17.0 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 27 @ 3493 6 @ 3427 17.7 19.4 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW DITCH GAS 51 @ 3277 0 @ 3498 CUTTING GAS @ @ CHROMATOGRAPHY(ppm) METHANE(C-I) 10073 @ 3267 100 @ 3498 ETHANE(C-2) @ @ PROPANE(C-3) @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ AVERAGE 12.5 2745.5 TRIP GAS= WIPER GAS-- 25 SURVEY= CONNECTION GAS HIGH= AVG= CURRENT 2 CURRENT BACKGROUND/AVG 2 HYDROCARBON SHOWS MAX GAS @ 3277' = 51u (C-1 ONLY) IN CLEAN MED GR SAND INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS CLYST/MUDST, COAL AND CARB SHALE PRESENT LITHOLOGY TUFFACEOUS CLYST/MUDST AND CARBON SHALE DAILY ACTIVITY SUMMARY DRILL TO 3525', WIPE HOLE 5 STDS AND DRILL AHEAD. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file ://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001002.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 03, 2000 TIME 23:52:57 DAILY WELLSITE REPORT DEPTH 4015 YESTERDAY 3575 24 Hour Footage 440 EPOCH LOGO . . PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 132.0 @ 3997 5.0 @ 3653 27.3 15.2 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 29 @ 3933 3 @ 3811 17.2 15.3 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 4004 MW 10.5 VIS 52 PV 17 YP 28 FL 4.6 Gels 13-19-23 CL- 1000 FC I SOL 11.5 SD 0.25 OIL 0.5 MBL 18 pH 9.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 134 @ 3996 0 @ 3605 17.3 TRIP GAS= CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 32015 @ 3989 113 @ 3605 3391.0 CONNECTION GAS HIGH= 91 ETHANE(C-2) @ @ AVG= 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 18 PENTANE(C-5) @ HYDROCARBON SHOWS MAX GAS @ 3996' = 134u (C-1 AND TRACE C-2) IN COAL INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, GRANULE TO PBL SAND, SANDSTONE, COAL,, CARB SHALE, TUFF MUDST/CLYST PRESENT LITHOLOGY COAL AND SAND DAILY ACTIVITY SUMMARY DRILLING AHEAD WITH PERIODIC FLOW CHECKS. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file ://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001003 .ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 04, 2000 TIME 23:59:00 DAILY WELLSITE REPORT EPOCH LOGO DEPTH 4136 YESTERDAY 4015 24 Hour Footage 121 PRESENT OPERATION= BACK REAMING TIGHT HOLE CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 71.3 @ 4028 6.8 @ 4126 25.7 26.7 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 18 @ 4050 3 @ 4117 10.6 8.7 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: N/A MW ViS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 22 @ 4024 0 @ 4125 9.7 TRIP GAS= 56 CU'I-FING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 4540 @ 4024 343 @ 4125 2180.4 CONNECTION GASHIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 5 i PENTANE(C-5) @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND PRESENT LITHOLOGY SAND, CONGLOMERATIC SAND DAILY ACTIVITY SUMMARY DRILL TO 4136', BACK REAM TIGHT HOLE, PUMP LCM TO STOP FLUID LOSSES, BACK REAM. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001004.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 05, 2000 TIME 24:00:00 DAILY WELLSITE REPORT EPOCH LOGO DEPTH 4136 YESTERDAY 4136 24 Hour Footage 0 PRESENT OPERATION= CIRC ON BOTTOM CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT @ @ Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS= 590 CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) @ @ CONNECTION GAS HIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 11 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY POOH, TEST BOPE, RIH, SLIP AND CUT DRILL LINE, RIH AND WASH DOWN APPRX 60' TO BO'I-I'OM Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file ://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001005.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 06, 2000 TIME 24:00:00 DAILY WELLSITE REPORT DEPTH 4517 YESTERDAY 4136 24 Hour Footage 381 EPOCH LOGO PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 121.7 @ 4355 3.2 @ 4458 27.4 14.0 ftJhr SURFACE TORQUE @ @ amps WEIGHT ON BIT 36 @ 4282 2 @ 4136 19.9 26.4 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 166 @ 4415 1 @ 4225 24.6 TRIP GAS= CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY=. METHANE(C-I) 33424 @ 4415 306 @ 4225 4738.2 CONNECTION GAS HIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ !HYDROCARBON SHOWS MAX GAS @ 4415' IN COAL = 166u (C-1 WITH TRACE C-2) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATIC SANDS, TUFF, TUFFACEOUS SILTSTONE, CARBONACEOUS SHALE AND COAL PRESENT LITHOLOGY TUFFACEOUS SILTSTONE AND CONGLOMERATIC SANDS DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 4136', Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTjxhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001006.ht 10/25/00 Daily Report Page 1 ot'l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 07, 2000 TIME 23:56:11 DAILY WELLSITE REPORT DEPTH 4787 YESTERDAY 4517 24 Hour Footage 270 EPOCH LOGO PRESENT OPERATION= DRILLING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT'AVG RATE OF PENETRATION 72.7 @ 4545 4.6 @ 4602 23.2 16.3 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 37 @ 4701 5 @ 4607 27.3 29.0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL ~ TOOLS TO GAS SUMMARY(units) HIGH LOW DITCH GAS 187 @ 4565 2 @ 4605 CUTTING GAS @ CHROMATOGRAPHY(ppm) METHANE(C-I) 39396 @ 4565 606 @ 4605 ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ AVERAGE 23.7 4803.1 TRIP GAS: WIPER GAS: 25 SURVEY: CONNECTION GAS HIGH: 5 AVG= 3 CURRENT CURRENT BACKGROUND/AVG 6 HYDROCARBON SHOWS MAX GAS IN COAL @ 4565 = 187u (C-1 WITH TRACE ONLY OF C-2 AND C-3) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE, TUFF SLTST, CALC TUFF, CARBON SHALE, TUFF CLYST AND COAL PRESENT LITHOLOGY TUFF SLTST, CARBON SHALE AND SLTST, COAL DAILY ACTIVITY SUMMARY DRILL TO 4606', WIPE HOLE 8 STDS AND DRILL TO 4787'. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTj xhexp\CookInlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001007.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR PETER LEACH DATE Oct 08, 2000 TIME 24:00:00 DAILY WELLSITE REPORT EPOCH LOGO DEPTH 5000 YESTERDAY 4787 24 Hour Footage 213 PRESENT OPERATION= BACK REAMING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 56.7 @ 4942 3.4 @ 4861 19.8 16.0 fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 35 @ 4896 1 @ 4869 25.3 23.0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 45 @ 4882 1 @ 4989 6.9 TRIP GAS= CUTTING GAS @ @ WIPER GAS= 45 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 6895 @ 4882 385 @ 4989 1411.9 CONNECTION GAS HIGH= 7 ETHANE(C-2) @ @ AVG= 3 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 3 PENTANE(C-5) @ @ HYDROCARBON SHOWS MAX GAS IN COAL @ 4882' = 45u (C-1 ONLY) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFF SLTST, CARBON SHALE/MUDST, TUFF CLYST PRESENT LITHOLOGY T.D. IN SAND DAILY ACTIVITY SUMMARY DRILL TO 5000', WIPE HOLE AND BACK REAM. Epoch Personel On Board= 4 Daily Cost 1925 Report by: S. HARNER file://J:\NTj xhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001008.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR Peter Leach DATE Oct 09, 2000 TIME 24:00:00 DAILY WELLSITE REPORT DEPTH 5000 YESTERDAY 5000 24 Hour Footage 0 !"~-1 EPOCH LOGO PRESENT OPERATION= E LOGGING CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ fi/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT @ @ Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS= 14 CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) @ @ CONNECTION GAS HIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY POH, RUE LOGGERS, LOGGING Epoch Personel On Board= 4 Daily Cost 1925 Report by: L. PRICE file://J:\NTjxhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001009.ht 10/25/00 Daily Report Page 1 of l ANADARKO Lone Creek #2 REPORT FOR Peter Leach DATE Oct 10, 2000 TIME 24:00:00 DAILY WELLSITE REPORT EPOCH LOGO DEPTH 5000 YESTERDAY 5000 24 Hour Footage 0 PRESENT OPERATION= RIH (OPEN END) CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ flJhr SURFACE TORQUE @ @ amps WEIGHT ON BIT @ @ Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS= CUTTING GAS @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) @ @ CONNECTION GAS HIGH= ETHANE(C-2) @ @ AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY E LOG, RIG DOWN WlRELINE, RIH (OPEN END) Epoch Personel On Board= 4 Daily Cost 1925 Report by: L. PRICE file://J:\NTjxhexp\Cooklnlet\WestRegional\Moq_Neph\LoneCreek2\Mudlog...\20001010.ht 10/25/00 Days vs. Depth ~^vs vs. [~.~. ANADARKO LONE CREEK #2 [~ EPOCH 0.00 -1000.00 -2000.00 -3000.00 -4000.00 -5000.00 -6000.00 I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 DAY Page 25 Mud Record EPOCH ..... Mud Report Anadarko Lone Creek #2 Moquawkie Field Date ;.Depth MW ViS PV YP] Gels FL ,Cake Sol O/W Sand MBT PH Pm Cl 9/12/00 90' 10.0 75 12 48 30/40/ - - 6.00 /94 1.00 8.0 - 300 9/13/00 245' 10.0' 85 11 28 20~35~50 nc - '8 0~92 2.00 22.0 8.0'- 300 ..9/14/00 245' 1010 70 22 27 7/15/26 - 8 0~92' 1.00 22.0 8.0 0.00 600 9/15/00 245' 10.1 72 22 27 7/15/26 . . 8 0/92 1.00 22.0" 8.5 0.00 600 9/16/00 245' 10.1 60 13 18 35/45/60 - - 8 0/92 1.00 20.0 11.5 - 300 9/17100 472' 10.2 43 14 i0 36~48~60 13.0 3132 10 0~90 1.00 '18.0 11.5 2.40 300 9/18/00 980' 10.2 41 ~1 9 17/30/45 13.0 3/32 10 0~90 1.00 18.0 10.5 1.10 300 9/19/00 1,001' 10.1 50 19 9 5/25/30 13.0 3/32 10 0/90 mr 18.'0 10.0 0.60 300 ' i gl20/00 1,001" 10.1 46 13 8 5/20/35 13.0 2/32 10 ' 0/90 mr '18.0 10.0 0.50 200 '9i21/00 1,001" 10.2 46 13 8 5~20~35 13.0"2/32 10 0i90 Tr' 18.0 10.0 0.50 200 ,9/22/00 .!.,00,1.' 1'0.1 46 13 '8 5/20~35 13.0 2/32 .!0 "0/92 Tr' 18.0 10.0 0.50 ,2,00 9/23/00 1,001' 9.6 ,,~45 - - - , - , , - , - - 9/24/00 1,018' 10.1 40 .......... 9/25/00 1,'0i8' 10.5 52 11 23 9i11/11 ' ' 8.0 1~32 8 ' 0/92 '0.00 0.0 '10.0 0.10 i00 "9/26100 ;i,600' 10.5 54 15 25 ;i2/14/15 6.~' 113210 0190 "0.~;5' 7.5 8.5 0.15 ..... 600 9/2~/0,,0,.,. ,,1,,9,81' 1'0;5 50 13, 20 9/10/12 6.2' 1/32 i,,10, tr/90 0.3 10 9.0 0.35 900' 9/28/00 2,163' 10.5 48 12 18 8~8/10 4.6 i/32 10.51 tr/89.5 0.3 13'" 9.7 0.55 1100 9/29/00 2,475' 10.5 48 13 '18' 8/10/12 4.7 1'/32 10.5 tr/89.5 0.3 13 9.5 0.60 1200 9/30/00 2,899' 10.5 48 i4' 20 7/8~8 4.9 1/3'2' 1'0.5 {r/89.5' 0.3 i3 9.4 01'55 1100 10/1/00 3,218' "i0.5 50 14 22 8/'10/11 4.'6' '1/32' 11' "tr89.0 0.3 15 9.6 0.60 '~00 10/2/00 3,575' 1015 52 15 24 10~12j14 4.8 1/32 11 .5/88'.5" 0.3' 15' 9.2 0.'45 '1000 10/3/00 4,004' 10'.5' 52 1'7 "2'8' 13/19/23 "4.6' 1/32 ~1.5' '.5/88' 0.3 18 9.0 0.20 '1'0/4/00" 4,125' 10.5 53 15 28' 10/15J18 '4.7 1/32 11 trc89 0.3 18 9.0 0.20' '1000' 10/5/00 4136' 10.6 '54 15 24 9/15/2'1 4.6 1/32 il.5 'tr88.5 0.3 18 9.0 0.15 100(~" ..... 10/6/'00 451~' 10.1 46 14 20 9/13/18 4.8 1/32 9.5 tr90.5 0.3 16 9.0 0115 1000" 10/7/00 4787' 10 44 10 23 10/14/17 4.8 1/32 9.0 trc91 0.3 13 8.8 0.10 1000 'i0/8/00 5000" '10.2 45 ';Ii' 24 10/14/18 4.6 1/32 ~0.0 'trc90" '0.3 13 8.8 0.10 '900 , , , , ,,,, , , , , i i ii i i i i i i i iii Survey Record ( Survey Report I Anadarko Lone Creek #2 Moquawkie Field i i i Depth Angle Angle Length Depth Section NIS E/W Severity oloo' o.oo - ' 'o.oo' '- ' - - - ~ , 92.00' 1.00 - 92.00' 91.99' - - - - , , , , ,. , ,,, 245.00' 0.75 - 153.00' 244.97' - - - - 517100' 1.00 - 272.00' 516.93' .... '636.00' 2.00 ' '- i 19:00"" ' 635.86' - '- - - 972.00' 1.00 - 336.00' 971.81' .... 1,130.00; 1.00 . - 158.00'. '" 1.,.129.78' . - ' - - "' 1,156.00' ' 1100 - 26100' 1,155.78' . ...- . ., - ,- - 1', 383'. 00, t'.00 ' : ...... 22'~. 00,'" 1,382.75' .... 1,477.00' 1.00 - 94.00' 1,476.73' - ""- "- ' ' '- , , , ,,,, ,,, , i,604.00' 1.00 -. .... 1'27.00' ' 1,603'73' 7. ' . ' ~ .." , 1,731.00' 1.00 - '127.0~)' '1,730.73' .... " 1,837.00' 1.00 - 106.00' 1,836.73' - - - - 1,9i9.00' ' "1.00 .... - ....... 82.'0.0" '..' .... 1 ,'9!"8.72' - - -' ' - 1,98'~ .'00' ..... 1'.00 " ........ 62.00' ..... 1",980,'71' ' - ' - ' .... ... ....-"' ' 2,234.00' '" 1.00 ...... - ...... 253.00' "2,233.'7i' ' - - ..... ' ' - ' 2,391.00' 2.00 ' -' 157.00' 2,390.7d' - ' ' ' ' ' r ' ' 2,423.00' 1.00 ' ' '. - . .... 32100' . '. .2,422.70' . .' "". .- .' 2,486.00' 1.00 - 63.00' 2,485.70' - - - - .2,547'00' ' 1.00' ., . .-., , 61.00' 21546.69' - .- .... ;.. , .-.. 2,742.00' 1.00 - 195.00' 2,74i .69' .... "2,833.00; ..1.00 '" ' .-'".'.... 'i.'"'.9!.00'.' '. '.."2,832.'6c~' ' . .- - , ~ ......... . 2,927.00' 1.00 - 94.00' 2,,926..68' . - - 3,084.00' I , 1 '00 .... ' .... 157.00' , I .3,083:68', - . I I I ' I I : .... 3,210.00' ' ' ' .......... 1.00 - 126.00 3,209.66 .... ' 3,324.00, 1.00 - 114.00' 3,32~.'66' .... 3,493.00' 1.00 - 169.00" ' 3,492.66' .... .' 3,620.00' 1.00 '-' ' ' 1'27.00' "3,619.66' - -' ........ ' .... - : : 3,7'15.00' . 1.00 .... - ..... 95.00' . 3,7!4.65'. - _ .-.. .. 3,933.00'. ..... 1.00 . - 218.00'. 3,9,32.62'' .... - . .- - . - . "4,061.00' 1.00 - 128.00' 4,060.62' - - - - . 4,;125.00' "'2.00' " -. ' 64.00'~ ....... , 4,!24.62' ....- . .................. -. . - - 4,161.00~' 2.00 . . .;. 36.00' 4,160.61' - - ... - - ' 4,283.00' 2.00 - 122.00' ' ..... 4,28~'.61~'' - - - - 14,470.00' 2.00 - 18~'.00' 4,469.49' - - - - ' I 4,690. O0 3. O0 - 220.00' 4,689.46' - - - - ~ , , 4,818.00' 5.00 - 128.00' 4,817.41' - - - - 4,851.00' 7.00 - 33.00' 4,850.39' - - - - 4,883.00' 5.50 - 32.00' 4,882.37' - - - - , '4,915.00" 6.00 - 32.00' 4,914.20' - - - - , , , . ..4,947.00' 6.00 - 32.00' 4,946.18' - - - - 4,979.00' 6.00 - 32.00' 4,978.16' - - - - 4,990.00' 6.00 - 11.00' ' '4,989.16' - - - - , , , Bit Record Bit Record Anadarko Lone Creek #2 Moquawkie Field Bit # Size Make Serial # Type Jets In ' Out, Feet Hours A~g. ROP NB~I 17.50" STC LW0231 DSJC 3x2.4, lx12 0' 92' 92' 1.5 61.3 NE~2 12.25" REED LU8860 EHT11 3)(24 92' 244' 132' n/a n/a n/a 17.50" n/a 5086169-8 HOLE OPENER 92' 227' 135' n/a n/a NB~3i 12.25" REED LU8736 EHT11 3X24 244' 270' 36' n/a n/a NB~i 8.50" HTC :841A4MX1 A632M 3x13,1x14 270' '1,001' 731' 15.!. 47.3 RR 12.25" REED LU8736 EHTll 3x24 270' 998' 728" 10.0 nla RR 8.50" HmC .e4~A4Mx' A632M 3X13,1X14 1,001; '1,018' 17' 210 40.2 NB#5 8.50" HTC L841.B. 5 MXCI' ~ txgi2x12,1x13 1,01e' 2,163' ~ 1,145' 5.5.0 .....35.4..' NB#6 8.50" HTC LO2DE MxC1 1x!0,.2x. 12,1x13 2,.163'.4,136' . 1.,973' 100.0 28.6 , NB#7 8.50" HTC LO6DE , , MXC1 , 1x10,,2x12,,lx13 4,136' 5,000' 864' 57.,9 .... 24,.2 , INote: Numbering sec~uence ,not consistent with IADC report.. All o{her Values {,rom I'A, DC report unleSS U,n,availal31e. ' , ' ' , I Formatiott Log
