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Home My WebLink About203-209• • -~«,__ -_-~. MICROFILMED 03/01 !2008 DO NOT PLACE ~:- ` _ ~~,> ,~,: ~,,: r ANY NEW MATERIAL UNDER THIS PAGE F:\L,aserFiche\C~rPgs_Inserts\Microfilm Marker.doc . . MEMORANDUM TO: Jim Regg, P .1. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ,/j .~ . G' 1l \ 1) 7 ,c.....,q DATE: June 12, 2007 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: location Inspection Pioneer (Evergreen) Kashwitna lake#1 PTD203-209 Tuesdav. June 12. 2007; I traveled to the Pioneer (Evergreen) coal bed methane exploration wells Little Su #1 ,Houston Pit #1 Sheep Creek #1, Kashwitna lake #1 and Slats #1 to verify location clearance. The exploratory locations were clean with no evidence of past drilling activity. SUMMARY: I recommend the above mentioned 5 locations be given final clearance approval Attachments: Kashwitna lake #1.JPG 5CANNED JUL 2 0 2007 2007 -0612_Location_ Clearance_Pioneer _KashwitnaLk-1_cs.doc Location Clearance Inspection - Kashwitna Lake Photos Scheve ---¡ 2007 -0612_Location_ Clearance_Pioneer _KashwitnaLk-1_ cs.doc . . March 1, 2004 Bob Crandall Petroleum Engineer Alaska Oil and Gas Conservation Commission (AOGCC) 333 West ih Ave. #100 Anchorage, AK 99501-3539 ~.................."............J'. . . .... ,~,,," "J "',.. .' . .', -"'0~ -.:-, '. . '. RE: Well Completion Report (Form 10-407) for Kashwitna Lake #1 Dear Mr. Crandall: Attached is the 10-407 form and attachments for the Kashwitna Lake #1. Hole conditions and mechanical problems did not allow the well to reach its intended total depth; the well was abandoned according to the approved plan. Core photos, chips and reports will be submitted to the Alaska Oil and Gas Conservation Commission as soon as they are available. If you have any questions, please feel free to contact me at 907-355-8569 or shaneQ@everQreenQas.com. Sincerely, SCAN~tZ1) 1 Z Shane Gagliardi Petroleum Engineer AU)-itClet. STATE OF ALASKA ALASKA 01 L AND GAS CONSERV A TIONCOMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . . 1a. Well Status: OilO GasO PluggedO Abandonedl8l SuspendedO WAGO 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJO WINJO WDSPLO No. of completions Other Service -0 StratiQraphic Test 181 2. Operator 5. Date Comp., Susp., 12. Permit to Drill Number: Name: Evergreen Resources Alaska Corp. or Aband.: 2/14/2004 203-209 3. Address: P.O. Box 871845 6. Date Spudded: 13. API Number: Was ilia, AK 99687 12/31/03 50- 283-20106 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: See 7, TWN 20N, RNG 4W 2/8104 Kashwitna Lake #1 Surface: 1847' FNL and 2050' FWL Top of Productive 8. KB Elevation (ft): 15. FieldlPool(s): Ground Level Wildcat Horizon: Same as Above 9. Plug Back Depth (MD + Total Depth: 1770' MD TVD): Surface (abd) 4b. Location of Well (State Base Plane Coordinates): (NAD 27) 10. Total Depth (MD + TVD): 16. Property Designation: 1770' State of Alaska Surface: x- 487747.09 y- 2866054.57 Zone-4 11. Depth where SSSV Set: 17. Land Use Permit: TPI: x- 487747.09 y- 2866054.57 Zone-4 ADL 389316 NIA feet MD TotalDepth: x- 487747.09 y- 2866054.57 Zone-4 19. Water Depth, if Offshore: 20. Thickness of 18. Directional Survey: Yesl8l NoD Permafrost: NIA NIA feet MSL 21. Logs Run: Gamma Ray, Spontaneous Potential, Caliper, Array Induction, Compensated Neutron Density, Sonic, Inclination Survey 22. CASING, LINER AND CEMENTING RECORD CASING WT. SETTING DEPTH MD SETTING DEPTH TVD AMOUNT SIZE PER GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED FT. 6" 17 LP 0 209 0 209 6.125 16 sx Portland cmt 4.5" 14.4 X42 0 512 0 512 5.5 18 sx Portland cmt 23. Perforations Open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None N/A NIA N/A N/A NIA N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None None I 26. PRODUCTION TEST Date of First Production: Abandoned Method of Operation (Flowing, Gas Lift, etc.): Abandoned Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: N/A Test Period- Flow. Tubing Casing Pressure: Calulated - Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press: 24-Hour Rate 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Separate core analysis will be submitted. Form 10-407 Revised 4/2003 CONTINUED ON REVERSE SIDE NAME GEOLOGIC MA MD 29. FORMATION TESTS 28. TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Quaternary Gravel o - 422' o - 422' None Sterling Formation 422' - 1770' 422' - 1770' 30. List of Attachments: Daily reports, wireline logs, mud logs, inclination survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gaaliardi Printed Name Shane Gaaliardi Title Petroleum Enaineer Signature Phone 907-355-8569 Date 3/1104 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 4/2003 Well Name Kashwitna Lake #1 12/19/2003 12/20/2003 12/22/2003 12/29/2003 12/30/2003 12/31/2003 1/1/2004 1/2/2004 1/3/2004 1/4/2004 1/5/2004 1/6/2004 1/7/2004 1/8/2004 1/9/2004 1/1 0/2004 1/11/2004 1/12/2004 1/13/2004 1/14/2004 . . =\'=I~el~== RESOURCES{ALASKA)COR~ Â Subsidiary of Evergreen Resourœs, Inc. Daily Drilling Summary Location API Permit to QTR I See I Twn I Rng Number Drill SEfNW I 7 I 20N I 4w [)-283-201 ( 203·209 Plow snow from location and right of way. Snow is approximately 30 inches deep. Clear road and begin clearing brush on site. Large brush piles and secondary growth from previous disturbance cleared. No trees damaged for site constr. Clear cellar and set culvert. Wait on Layne Christiansen. MIRU drilling support equipment. MIRU Layne Christiansen CS 4000 drilling rig, solids control van and gas detection. Mix bentonite mud. Make up 5-1/2 de to 6-1/8 varel bit. Spud @ 10:30 AM. Drill to 16' and evaluate mud. MW = 9.1 ppg and Vis = 45. Drill 6-1/8" hole to 72'. Boulders begin @ 66'. SDON. Troubleshoot generator; thaw equip. Drill 6-1/8" hole from 72' to 172'. Pipe wrench fell in hole. Log surface hole wi gamma, SP and induction. Loggers TD = 130'. Hole sloughing; pull tight @ 102'. SDON. Thaw rig. Drive one jt 8-5/8 csg. SDON Thaw equipment. Chuck broke; repair. TIH. Tag wrench @ 130'. Attempt to push to bottom; unsuccessful. SDON. Thaw rig. TIH wi core bit and bbl. Wash down to 120'. Swabbed river gravel into well bore when retreiving inner tube. Cannot get inner tube down. Mud froze while working inner tube. SDON. Warm rig and mud pits. Hydraulic fittings on chuck broken again; replce. TIH wi core bit, core bbl and DP. Tag fill @ 110'. Clean hole. Circulate hole. Core drill to 120'. POOH wi inner tube. Problems getting new inner tube latched. Short trip to 100' to clear core bbl. Gravel sloughing. Clear core bbl and trip back to bottom. Back on bottom with core bit and rotating. Pump pressure and torque is very erratic. Think bit is bad. Round trip bit. Core bit is in good shape. Tag fill @ 80'. Attempt to clean hole back to 130'. Not making any hole. POOH wi core bit, core bbl and DP. PU tri-cone, DC and DP. TIH; tag fill 80'. Drill w/ tri-cone to 130'. Condition hole. POOH and LD tri-cone, DC and DP. PU and TIH wi core bit, core bbl and DP. Tag fill @ 80'. Condition hole, attempt to wash to 130'; unsuccessful. Attempt to clean fill wi core bit; unsuccessful. Wait on orders. Get verbal approval from AOGCC to abandon current hole and skid rig. Mix 18 sx, 5 bbls, cement @ 12.5 ppg. Pump cmt through drill string @ 90'. Circulate one half bb112.5 ppg cmt to cellar. SDON; wait on Denali Drilling rig. Wait on Denali rig. RDMO Layne Christiansen to staging area for rig maintenance. MIRU Denali rig. Drilling rig on site @ 17:00. SDON. Wait on Denali Drilling equipment to mob from Anchorage. Wait on Denali Drilling. Mob final Denali Drilling equipment from Anchorage. Warm rig. Weld hammer shoe to 6 inch casing. Finish cutting and welding hammer shoe. SDON Stand up rig derrick and level rig. Lay derrick down to repair hose brace and hydraulic fittings. I 69 feet. PU water @ 55' and continues to 65'. (Water sample @ 69' - 96 ppm TDS 10.3 degrees C). 89 feet. PU more water @ 80'. Water sample @ 89' - 79 ppm TDS @ 6.6 degrees C. 109 feet. Water sample @ 109' - 85 ppm TDS @ 6.4 degrees C. 169 feet. Water sample @ 169' - 71ppm TDS @ 4.3 degrees C. 189'. Water sample @ 189' - 73 ppm TDS @ 4.3 degrees C. Haul 3 loads fresh wtr to disposal. PU lots of water; too much water for hammer. Water sample @ 209' - 73 ppm TDS @ 4.3 degrees C. Finish drilling to 209'. Water sample @ 209' - 73 ppm TDS @ 4.3 degrees C. RDMO Denali drilling to Sheep Creek. SDON. MIRU Layne Christiansen rig. Hard shack rig and set up tents and tarps. Dig new cellar and set culvert @ 3' BGL. Wait on orders for cementing 6" csg. Wait for cement and cement additives. Total Depth 1770' MD Spud Date 12/29/2003 . . Cement 6 inch casing wi 16 sx cement - 225 gal @ 12.5 ppg. Displace cmt wi 263 gal fresh water. No lift pressure. Cement from top wi 50 gal 12.5 ppg cmt. Wait on cement. . . 1/15/2004 1/16/2004 1/17/2004 1/18/2004 1/19/2004 1/20/2004 1 121/2004 1/22/2004 1/23/2004 1/24/2004 1/25/2004 1/26/2004 1/27/2004 1/28/2004 1/29/2004 1/30/2004 1/31 12004 Wait on cement. Cement in cellar still not set. Make up tricone bit and bit subs. TIH wi bit to tag cmt. Tag cmt @ 200'. Mix bentonitelbarite mud. Mud weight 9.8 ppg and 38 vis. Drill new 5-1/2" hole from 209' to 320'. Make several short trips; no fill. Circulate hole. POOH wi tricone bit and TIH wi core bit and bbl for taking spot core. Core 4'. POOH wi inner tube. Full of gravel. POOH wi core bbl and bit. Still in gravel. TIH wi tricone bit. Wait on drill pipe. Drill to 405'. Bit jumping and torquing. Pull bit for penetration rate. POOH wi tri-cone bit. Bit is in good shape. Begin to TI H wi 5-118 button bit. Generator went down. Wait on generator repairs. Drill from 405' to 505'. No more drill pipe. POOH wi tricone button bit. TIH wi core bit and bbl to take 4' spot core for lithology confirmation; Chuck froze and broke. Reapir chuck. Finish POOH wi tri-cone. TIH wi core bit and bbl. Core bit on btm. Core bbl plugged; cannot pump through it. Round trip core bble to clear plug. Core 7' to 512' to check lithology. Cannot pull inner tube. POOH wi DP to retreive core. Finish POOH wi core bit and bbl. Some river cobbles; most likely fill. Appears that unconsolidated sand is the lithology at current depth. Weld first 300' of 4.5" csg. Begin to screw together last 200'. Finish TIH wi csg. Land csg @ 510'. Circulate mud out of hole. Cement 4.5" csg w/18 sx; 198 gal wtr, 40 Ibs Calcium Chloride @12.5 ppg. Lift pressure - 200 psi; full returns. Circ lite cmt to cellar. SD backside on suck; fill from top. Wait on cmt. RD Core rig to lift on timbers to make room for BOP. Timber rig; rig not over hole. Will slide rig in the AM. SDON RU mud plant. Hard shack rig. Test csg to 1500 psi; test BOP to 1500 psi; witnessed by John Spalding AOGCC. TIH wi core bbl, bit and DP. Have to wash down due to heaving sand at shoe. Core from 515-520. Sand and gravel fill; core bble jammed. Core from 520'-530'. Recover 7' of core. Core from 530'-538'. Recover 6.5' core. Core bbl jammed and bit burned; prepare to POOH. Make bit trip. Replace bit and TIH. Core from 538'-582'. Recover 40' core; recover 91 percent. Inner tube would not latch on last run. Prepare to POOH. Inner tube would not latch. Round trip to repair. Core from 582'-605'. Recover 31' of core; recover 135 percent - abundant sand fill. Core from 605'-617'. Recover 17'; recover 143 percent. Heaving sand. Blew main hydraulic line. Rig down for repairs. Core from 617' to 738'. Recover 114' of core; 95 percent. Problems wi heaving sand. Core from 738'-897'. Recover 159' of core; 100% recovery. Sand sloughing is settling down. Core from 897' - 986'. Recover 88.8'; 96 percent. Problem w/ heaving sand. Redrill fill @ 954' - 968'. Inner tube wouldnot latch. Rods sanded in. Round trip pipe to clear. Hit sand 200' off of bottom; heavy sand 90' off bottom. Core From 986' - 991'. Recover l' of core. Core from 991' - 992'. Hole caving in. Core from 992' - 1043'. Recover 48.1 '; 94 percent. Bearings in chuck froze. Wait on parts; repair. Core from 1043' -1094'. Recover 51.3'; 100 percent. Core from 1094' - 1113'. Recover 19'; 100 percent recovery. Round trip pipe. Replace 5' tools wi 10' tools. Wash 200' back to bottom. Core from 1113' - 1168'. Recover 34.3'; 62 percent recovery. Drop core, chase tube. Broke wireline. POOH wi rods, bit and bbl. Suspect that the core bit is under gauge. Wait on new bit. TIH to 970'. Sanded tube in. POOH to 570'; clear tube. TIH to 970' and wash to bottom. Problems wi high pump pressure. Core from 1168' - 1213'. Recover 45'; 100 percent recovery. Core from 1213' to 1274'. Rods tight between runs. Recover 58'; 95 percent recovery. Core from 1274' to 1324'. Recover 50'; 100 percent recovery. Hit unconsolidated sand; hole filling. Have to wash and redrill at every connection. Washing hole; keeps refilling w/ sand. High torque. High torque. POOH to 800'. Drill 824' to 826' Pipe stuck. . . Work stuck pipe. Twisted off @ 900'. Fish twisted DP wi center spear. Grab Dp and POOH. POOH wi fish. Repair rig. Wait on mud additives from Fairbanks. Change bit and bit subs to higher flow bit. Replace wireline spool and mainline. TIH to 900', tag swelling clays and sand. Wash 400' to 1324' . . 2/1/2004 2/2/2004 2/3/2004 2/4/2004 2/5/2004 2/6/2004 2m2004 2/8/2004 2/9/2004 2/10/2004 2/11/2004 2/12/2004 2/13/2004 2/14/2003 Hole cleaned back to bottom. Core from 1324' to 1351'. Sand rings causing problems inside DP. Redrilling fill and washing 7' back to bottom on each pull. Recover 8.3'; 30 percent recovery. Clean hole. Core from 1351' to 1354'. Recover 3.2'; 107 percent recovery. Hole caving. Clean hole. Core from 1354' to 1363'. No recovery. Pull back to work through swelling clays. Washing back to bottom. Bad gravel zone 10' off bottom. Need to make a bit trip. Decide to cement hole. Wait for cement to be delivered from Wasilla. Mix and pump 10 sx cmt @ 13 ppg wi 3% CaCI2. POOH wi HQ rods. Wait on cmt to set. Wait for cmt to set. TIH wi new core bit. Start washing in 220' off of bottom. Core from 1363' to 1397'. Recover 23'; 68 percent recovery. Did not tag cmt. Rocks are poorly lithified and caving. Core from 1399' to 1402'. Bad hole conditions; hole sloughing. Make decision to tricone hole to 2000'. Round trip DP. Change to 3-3/4" MT Varel bit. Wash back to bottom. Drill w/ tricone from 1402' to 1472'. Short trip pipe twice to reduce pump pressure. Wash back to bottom. ROP = 8.75 ftIhr. Washing back to bottom. Pump pressure @ 1100 psi. Make a bit trip. Suspect bit cutting under gauge hole; confirmed. Gauge row badly worn. Switch out MT bit for BB. Wash back to bottom. Drill 3-3/4" hole from 1472' to 1557'. POOH wi bit and HQ DP. Wait on orders; having mud analyzed by MI Fluids. MW: 9.2, pH: 8.1, PV: 17, YP: 17; Solids 12%; CGS 7% Make decision to run NO rods to reduce pump pressure. Wait on cross over subs. Sub up to NQ pipe and TIH wi 3-34" button bit and 20' HQ pipe for stiffness. Start washing @ 1220'. Drill 3-3/4" hole from 1557' to 1645'. Drill 3-3/4" hole from 1645' to 1770'. Bean pump on rig went out. Love Joy coupler broken. PU 60' off of bottom. Attempt to POOH after working on a auxilliary pump for four hours. Rods are stuck in hole. SD waiting on pump parts. Swaco solids control van shells main impellar shaft on centerfuge. Centerfuge is down waiting on parts. Wait on parts for Bean pump. Rig maintenance. Work on stuck pipe. Attempt manual back off to break NQ rods below BOP. Rods broke deep; cannot screw back into fish. POOH w/17 20' stands of NQ rods. Rods broke @ 340'; NQ pin sheared. TOF @ 340'. NO box wi part of NQ broken pin looking up. Attempt to repair bean 35 pump. Sent parts for Bean 20; not Bean 35. Waiting on correct pump parts. Re-Ievel and block rig. Rig shift due to soft ground and warming temperatures. Wait on correct pump parts for Bean 35 pump. Repair Bean 35 Rig pump. TIH wi HQ wash pipe. Tag TOF @ 340'; had to rotate to get over NQ pipe. Wash every fifth joint to maintain clean hole. Tag bridges @ 1330'. Tag fill @ 1400' and wash continuously to x-over @ 1690'. MW 9.2; Vis 48. TIH wi NQ Rods and Bowen spear. Stab into NQ pipe @ 340'; fish will not move. Wait on B rods and cutter. Wait on B rods and cutter. B rods and cutters arrive. Rack rods and TIH wlcutter. Chuck jaws fail. TIH to fish B rods and cutter. Tag B rods and screw into. Pressure cutter and attempt to cut, unsucessful. POOH. Wait on second cutter. TIH wlnew cutterto 1689', attempt to cut, unsucessful. POOH. Clean cutter piston and TIH to 1689'. Second attempt to cut NQ rod unsucessful. POOH and clean out cutter. TIH to 1689', third attempt to cu NQ rods sucessful. POOH wi B rods, NQ rods that were cut and HO wash pipe. MIRU Reeves wireline for logging. TIH wlGamma, SP, Comp, ND, Duel Induction and sonic log to 1576'. Log hole from 1576' to 400'. Standby for cement. TIH w/ NQ rods and core bbl to 1586" Take survey @ 500' - degree, 1000' - 1 degree and 1500' -1 degree. Mix 13 sx portland cement, 229 gal @ 3% calcium chloride and pump. POOH wi NQ rods to 1000' Mix 13 sx portland cement, 229 gal @ 3% calcium chloride and pump. POOH 200' and pump next batch, . . 229 gal of cmt. Repeat 2 more times. Pump total of 65 sx cmt @ 12.1 ppg and 3% CaCI2; circulate 4 bbls cmt to pit. Begin RDMO to Sheep Creek #1. Prepare site for reclamation and P & A. Weld AOGCC name plate on 4 1/2" casing. . . Kashwitna Lake Retrieval Run Percent Time Time at Time number Date From To Cut Recovered Recovery Start out Surface (min) 1 01/23/04 520.0 5.0 0.0 0% 1033 1035 2.0 2 01/23/04 520.0 525.0 5.0 1.5 30% 1107 1110 3.0 3 01/23/04 525.0 530.0 5.0 2.0 40% 1140 1143 3.0 4 01/23/04 530.0 535.0 5.0 5.0 100% 1208 1211 3.0 5 01/23/04 535.0 538.0 3.0 1.5 50% 1230 1233 3.0 6 01/23/04 538.0 538.0 0.0 0.0 0% 1303 1306 3.0 7 01/23/04 538.0 538.0 0.0 0.0 0% 1331 1334 3.0 8 01/23/04 538.0 539.0 1.0 1.0 100% 1556 1559 3.0 9 01/23/04 539.0 540.0 1.0 0.0 0% 1652 1656 4.0 10 01/23/04 540.0 545.0 5.0 5.0 100% 1733 1736 3.0 11 01/23/04 545.0 550.0 5.0 5.0 100% 1815 1818 3.0 12 01/23/04 550.0 555.0 5.0 4.0 80% 1844 1847 3.0 13 01/23/04 555.0 560.0 5.0 1.6 32% 1934 1936 2.0 14 01/23/04 560.0 562.0 2.0 5.0 250% 1958 2001 3.0 15 01/23/04 562.0 567.0 5.0 5.0 100% 2032 2035 3.0 16 01/23/04 567.0 572.0 5.0 3.5 70% 2100 2103 3.0 17 01/23/04 572.0 577.0 5.0 5.0 100% 2139 2141 2.0 18 01/24/04 577.0 582.0 5.0 5.0 100% 2230 130 120.0 19 01/24/04 582.0 586.0 4.0 3.5 88% 247 250 3.0 20 01/24/04 586.0 588.0 2.0 5.0 250% 318 320 2.0 21 01/24/04 588.0 589.0 1.0 3.0 300% 329 331 2.0 22 01/24/04 589.0 593.0 4.0 5.0 125% 358 400 2.0 23 01/24/04 593.0 597.0 4.0 5.0 125% 431 434 3.0 24 01/24/04 597.0 600.0 3.0 5.0 167% 508 511 3.0 25 01/24/04 600.0 605.0 5.0 0.2 4% 556 559 3.0 26 01/24/04 605.0 607.0 2.0 5.0 250% 620 623 3.0 27 01/24/04 607.0 609.0 2.0 4.0 200% 713 716 3.0 28 01/24/04 609.0 614.0 5.0 3.2 64% 756 759 I 3.0 29 01/24/04 614.0 617.0 3.0 5.0 167% 900 1440 340.0 30 01/24/04 617.0 619.0 2.0 0.0 0% 1508 1511 3.0 31 01/24/04 619.0 623.0 4.0 3.5 88% 1541 1544 3.0 32 01/24/04 623.0 626.0 3.0 5.5 183% 1635 1638 3.0 33 01/24/04 626.0 631.0 5.0 0.0 0% 1707 1725 18.0 34 01/24/04 631.0 632.0 1.0 5.0 500% 1725 1728 3.0 . . 35 01/24/04 632.0 637.0 5.0 5.0 100% 1811 1814 3.0 36 01/24/04 637.0 642.0 5.0 5.0 100% 1843 1847 4.0 37 01/24/04 642.0 646.0 4.0 5.0 125% 1936 1939 3.0 38 01/24/04 646.0 651.0 5.0 4.0 80% 2003 2006 3.0 39 01/24/04 651.0 656.0 5.0 5.0 100% 2027 2030 3.0 IY MI'V'~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032090 Well Name/No. KASHWITNA LAKE 1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-283-20106-00-00 MD 1770 TVD 1770 Completion Date 2/14/2004 Completion Status P&A Current Status P&A UIC N -_._-~._----- -~'--'----~-~-,._~~-~,-~~~- ~--~,- _._.~---'------,._----_.~-_._~_.~--~,----~.__.- -- --~~ REQUIRED INFORMATION Mud Log Yes Samples No Name Induction/Resistivity Log Log Scale Media Run No 1 Directional Survey No (data taken from Logs Portion of Master Well Data Maint . Interval OH/ Start Stop CH Received Comments 400 1576 Open 6/21/2004 Son ic/Neutron/Porosity/GR/ SP 400 1576 Open 6/21/2004 soniclNeutron/porositY/GR/1 SP 400 1576 Open 6/21/2004 ARRAY INDUCTION, PHOTO DENSITY, DUAL I SPACED NEUTRON 400 1576 Open 6/21/2004 PHOTO DENSITY, DUAL I SPACED NEUTRON I 400 1576 Open 6/21/2004 ARRAY INDUCTION, 0 1770 Open 6/21/2004 DUAL_SPACED NEUTRON I 5 IN. -20FT. Sample . Set Number Comments -"---_._-~~.~._~-~._---~-~_._------ ~-~-~---_._.~- DATA INFORMATION Types Electric or Other Logs Run: Text to large see 10-407 Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ï: : ~:: 1::::: L4/~ I Sonic Sonic .~~--- 25 Blu 25 Blu 25 Blu Col Interval Start Stop Sent Received I nd uction/Resistivity Density Lithology Well Cores/Samples Information: Name f-~--~~_~_ l ----~ -- ~-~- Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 12/22/2003. I J ADDITIONAL INFORMATION Well Cored? ~ N Chips Received? ¥..L.bI \í-f~IoI(<l '-<Q-r-f.- Daily History Received? Y/N Formation Tops Y/N Analysis Received? ¥-./.N--~' ~~.~--~.~ --- Comments: ;Vù - 40) L¡. çÍt,.. c¡.~ 7 ~~ ~ J/IC/ ~y y1l~( J,V\'[ ú) ç '-LL-V1~(¡'l . DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032090 Well Name/No. KASHWITNA LAKE 1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-283-20106-00-00 MD 1770 TVD 1770 Completion Date 2/14/2004 Completion Status P&A Current Status P&A UIC N -~._--~- .~--~ -----_.-.,.._------~-_.._--~-----"~-- Compliance Reviewed By: Date: _~_ -.-.-'-----.- . . . . January 13, 2005 PIONEER NATURAL RESOURCES ALASKA. INC Howard Okland Petroleum Geologist Assistant Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Letter of Transmittal Subj: Evergreen Resources Alaska Corp's 2004 Five-Hole Core Program Dear Mr. Okland, I am enclosing with this correspondence, both an inventory of the continuously cored exploratory wells that were drilled in early 2004 by Evergreen Resources Alaska Corporation (Evergreen) and a data CD, per your request. The wells drilled include the Sheep Creek #1, Kashwitna Lake #1, Houston Pit #1, Little Su #1, and the Slats #1. Total well depths and cored footage (in parentheses) of these exploratory wells are as follows: Sheep Creek #1 - 1,369' (1,034'); Kashwitna Lake #1 - 1,750' (878.5'); Houston Pit #1 - 1,604' (1,548'); Little Su #1 - 2,125' (2,010'); and Slats #1 - 3,095' (2,685'). Total cored footage equates to 8,155.5 feet. Core from the five Evergreen exploratory wells is presently in a container at the Alaska Geologic Materials Center in Eagle River. If you have any additional questions or requests, please feel free to contact me. Sincerely, ?7~/f~ Michael A Belowich Coal Geologist Pioneer Natural Resources Cc: Robert Crandall - Alaska Oil & Gas Conservation Commission Matt Rader - Alaska Division of Oil and Gas John Reeder - Alaska Geologic Materials Center 1075 CHECK STREET. STE. 202 . WASILLA, ALASKA 99654 . MAIN: (907) 357-8130 . FAX: (907)357-8340 . . Well Name: Kashwitna Lake #1 ~ Ù:)- À ù '1 - Box Depth Box Depth Numbers Column Shelf Top Bottom Numbers Column Shelf Top Bottom (ft) (ft) (ft) (ft) 1 5 B 523.5 538.0 51 4 C 1011.0 1020.5 2 5 B 538.0 549.0 52 4 C 1020.5 1031.0 3 5 B 549.0 562.0 53 4 C 1031.0 1039.9 4 5 B 562.0 569.0 54 4 C 1039.9 1050.2 5 5 B 569.0 579.5 55 4 C 1052.2 1059.0 6 5 B 579.5 587.8 56 4 C 1059.0 1067.3 7 5 B 587.8 590.5 57 4 C 1067.3 1077.0 8 5 B 590.5 598.0 58 4 B 1077.0 1086.5 9 5 B 598.0 607.0 59 4 B 1086.5 1095.5 10 5 B 607.0 617.0 60 4 B 1095.5 1105.0 11 5 B 617.0 626.0 61 4 B 1105.0 1114.0 12 5 B 626.0 637.0 62 4 B 1114.0 1124.0 13 5 A 637.0 646.8 63 4 B 1124.0 1134.0 14 5 A 646.8 656.5 64 4 B 1134.0 1143.5 15 5 A 656.5 667.0 65 4 B 1143.5 1172.5 16 5 A 667.0 675.8 66 4 B 1172.5 1182.5 17 5 A 675.8 685.4 67 4 B 1182.5 1191.6 18 5 A 685.4 694.4 68 4 B 1191.6 1201.5 19 5 A 694.4 704.0 69 4 B 1201.5 1210.0 20 5 A 704.0 713.6 70 4 B 1210.0 1220.0 21 5 A 713.6 724.6 71 4 B 1220.0 1231.0 22 5 A 724.5 734.4 72 4 B 1231.0 1242.0 23 5 A 734.4 743.2 73 4 B 1242.0 1251.0 24 5 A 743.2 752.5 74 4 B 1251.0 1260.0 25 5 A 752.5 763.0 75 4 B 1260.0 1269.0 26 5 A 763.0 772.0 76 4 A 1269.0 1279.8 27 5 A 772.0 781.0 77 4 A 1279.8 1290.0 28 5 A 781.0 790.0 78 4 A 1290.0 1297.0 29 5 A 790.0 800.0 79 4 A 1297.0 1306.8 30 5 A 800.0 810.0 80 4 A 1306.8 1316.1 31 4 D 810.0 820.0 81 4 A 1316.1 1326.0 32 4 D 820.0 830.0 82 4 A 1326.0 1352.0 33 4 D 830.0 839.5 83 4 A 1352.0 1375.3 34 4 D 839.5 848.8 84 4 A 1375.3 1383.7 35 4 D 848.8 858.5 85 4 A 1383.7 1399.0 36 4 D 858.5 867.2 86 4 A 1399.0 1402.0 37 4 D 867.2 877.0 87 38 4 D 877.0 886.0 88 39 4 D 886.0 894.3 89 40 4 C 894.3 903.2 90 41 4 C 903.2 913.0 91 42 4 C 913.0 922.0 92 43 4 C 922.0 933.0 93 44 4 C 933.0 942.5 94 45 4 C 942.5 953.0 95 46 4 C 953.0 963.0 96 47 4 C 963.0 973.0 97 48 4 C 973.0 991.3 98 49 4 C 991.3 1000.5 99 50 4 C 1000.5 1011.0 100 (ll Jt¥- À_ ~ ç Slats # I Core Disposition . e ~ð3--àQ1 Subject: Slats #1 Core Disposition From: Shane Gagliardi <shaneg@evergreengas.com> Date: Thu, 20 May 200409:33:35 -0800 To: bob _crandall@admin.state.ak.us cc: Corri Feige <CorriF@EvcrgreenGas.com>, Scott Zimmerman <ScottZ@EvergreenGas.collJ>, Chris Cornelius <ChrisC@EvergreenGas.com> Bob, >From this year's core program, we have extracted approximately 8,000' of core. Of this core about 3,000' will be slabbed. Evergreen Alaska will donate all of the core to the state to fulfill the AOGCC requirements of 20 AAC 25.071 (b) (4). We understand that the donated core will be kept confidential for a minimum of two years. The slabbing and photographing process is lengthy; the anticipated approximate date for completion of the process and transferring the core to the state is March 05. If you have any further questions, please contact me @ 907-355-8569. Thanks, Shane I of I 5/20/20049:40 AM . . &03 'CY 0\ '~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P.I. Supervisor /Í _ - Û~b\lA ~~(1 ' DATE: January 28,2004 FROM: John Spaulding, Petroleum Inspector SUBJECT: Location Inspections Evergreen Resources Coal Bed Methane January 2004: I traveled to Evergreen Resources locations in the Mat-Su Borough. Susitna 1 ,Kashwitna 1 and Sheep Creek 1 are noted in this report. At present all wells are being drilled for core sampling purposes of the formations. I was notified of the Susitna 1 well after the rig had encountered some problems cementing surface casing. The well was suspended and the rig had moved off location when I arrived. There was probably a foot of new snow when I visited the location and and the casing and the location was pretty well covered over. I intend to revisit at a later date when the rig has returned or the well is P&Aed. Kashwitna 1 located North and West of Willow, AK: I observed a BOPE test and inspected the rig and location. Pictures were taken of the BOPE, rig and surrounding location. I observed the technique for water sampling, and to my estimations found it adequate. Sheep Cr. 1 located farther North and West from the Kashwitna location near the Parks Highway: I was only able to look at the location, as the rig had not moved in yet. I am questioning the requirements for a manual annular device and a manual valve for a blind ram. These are located under the rig floor as with all drilling rigs, but are not hydraulically operated from a remote location. If in the event of an influx of gas a person would have to lay on their stomach and have their face next to the top of the casing in order to close either portion of BOPE. Should we be requiring hydraulically operated BOPE? Should we relax the requirements for the manual BOPE? Hopefully the accompanying photos will help explain. SUMMARY; I inspected the above-mentioned locations and found all to be quite clean and orderly. A BOP test was witnessed, with no failures. Attachments: Photo's CONFIDENTIAL 2004-0128_Locations _ CBM_ Suisitna1_Kashwitna1_ SheepCk1.Js.doc . . Evergreen Resources - Pioneer CBM Project Inspections from January 11 and January 22, 2004 Photos from AOGCC Inspector John Spaulding ,_.",.".,,_. ,_."._n___ """._...._.__.,..,,."".,,."._.,,,...."'__ ~;:'-;-, , -~."- .~'l~'· ..'~ '.. -"-'-'--- .... ' 4ft Blowing casing dry Cuttings catcher ~ ~;-..;: ~~J ~_ ~. -'\.r ~. ~_~ OJ II · . ...... \'I'. .., ,,~ -I., : 'J .¡. _~" . c'... "': .,.~. .......- " I. . " , :". "'4.-, Welding casing 2 . . Cuttings and water return lines Rig and choke manifold Location - Kashwitna #1 3 . , ':Þï .,. .f!' ~ 4 :~f . ~.~ ~~~~~ ff191t ~··~,11' . ~)~ ~"~ , ~ . . ", It ''''I''I·.iÎIÌ.···..~ . AI.! . ... - III Gas buster 5 . . MEMORAND'M State oftlaska Alaska Oil and Gas Conservation Commission From: John Spaulidng Petroleum Inspector TO: Jim Regg yet1¿i 4(\Â{ùA' DATE: January 22,2004 P.I. Supervisor . l SUBJECT: Mechanical Integrity Tests Evergreen Resources Alaska Wildcat Kashwitna 1 PTD 203-209 NON- CONFIDENTIAL Well P.T€). Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING p Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intemal Radioactive Tracer Survey A= Temperature Anomaly Survey 0= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details 4.5" casing set at 5121 mdl md. Tested casing to 1500 psi for 30 minutes prior to drilling out. M.I.T.'s performed: 1 Attachments: none Number of Failures: Q Total Time during tests: 2 hrs. f£.~ MIT report form 5/12/00 L.G. 2004-0122_ Surf_ csg_Kashwitna#1-Íhs.xls 4/14/2004 12/30/2003 18:16 FAX 907 269 8943 SOA DIV OF OIL & GAS I4J 0011011 . . .:~o3-·ôlOI State of Alaska Department of Natural Resources Division of Oil and Gas DIRECTORS OFFICE 550 West 7th Ave #800 Anchorage, Alaska 995031-3560 (907) 269-8784 phone (907) 562-3852 fax DELIVER TO: Sharmon Stanbough Oran Woolley Bob Blankenburg Matt LaCroix Bob Crandall ADEC ADEC ADEC OHMP AOGCC 269-7508 269-2294 269-7600 907745-7112 276-7542 DATE: December 30, 2003 TOTAL PAGES: 9 FROM: Matt Rader phone (907) 269-8776 e-mail MatcRader@dnr.state.ak.us MESSAGE: Evergreen will begin drilling tomorrow on the Kashwitna Lake site. They have indicated they may use the following dri1ling fluid additives if needed: 1. Extreme Number One 2. Super Gel - X MSDS Datasheets are attached. RECEIVED DEe 3 x 2003 "'QI'~c..~ . J1!r AId T1_ I RECEtVED DEe 3 1 ZOO] AIiiI.'iIa(ja~If· -1 - a -d HI ~d OvEB S~IW 'f1>1S'f{1Q -l.SE-l.06 0Þ61ZZ5L06 ~;£t t0QlIBE/Zt HQ dat:£O EO DE g~Q packaging Extreme Number One C,)mes in 5 gal'en, high impact with a snap-on lid. 24 pa;\s per pallet . plastic paUs Mixing Add a small amount Df E.xueme Number ana to water in the mixing tal\!<. sprinkle slowly into turbulent water when mixer is on high. Increase \lie quantity .dded of Extreme Number One It hole conditions are ditticult. F:>r iest mixing, add extreme Number One to a small amount of ,egetable oil fin;t and then pour quiCklY loto turbulent water. ;~'r;nc;ple Use The Number One choice for demanding hole conditiOns when Bentonite Is una,ailable or unwanted. A one product drilUng fluid. Excellent tor winter. product doe. not _ze In container. Economical. Ultra High Grade ",eanS less prodUct required on jObS and!e$S product to By inlo remote s¡les. Litts cuttings and stabilizes the hole. Reduces torque and drag In the Þole. G.reatly reduces s",,,lIing of clays and shale.. Can be used to make stiff foam ier air drilling. Environment FriE 1'\dly. ExtrerT\~ly Effective- Description Ultra High Grade. AnIonic, ACrytamide CopOlymer iree flowing coarse white powder. in 'the 10rm of a WNtIl R.cc1" BC v 4' 1W9 · '1'e1:' [535-6 -- ~ ".,,.¡, '. ·1 ~ r4 ~ ..- ~e'wumberOne \ .- ~..'-..,,~ z.......:---'~:.:.:... ...... ~ r . t . ,.=t.... ....u.....,~~~...ca ~.' ~1\;..I'.c; l",f\V,""\,I,,,..=- IW\I""," UUII ./..:t~::· " .I " ;. 12/30/2003 18:16 FAX 907 269 8943 . .-...._---~ SOA DIV OF OIL & GAS . 141003/011 12/30/2003 18:16 FAX 907 269 8943 SOA DIV OF OIL & GAS ~ 004/011 . . U~~UU/ua lö;¥~ ~Al aO~53S5~Ya .lÜ1 H!:::>11:: PRCDliCTS 1/1)003..' OOÐ MATERIAL SAFETY DATA SHEET ~Vfir.BfA1r: ",¡E iii"A I .II, MOD&ICTU 1M. '!640 Me unlalf\vIøw Of., Whì\e ~,8C \/41" 2wt . 'T'6t le04ì S3S-lìUi FÞ: '.,.1 $3S0SQ. EMERGENCY- PHONE NO. (604) 535-6699 PAGE 1 OF S WHMIS HAZARQ INQEX: , DEGREE OF HAZARD: HEAlTH 1 FIRE '. 0 REACTIVITY . 0 OTHEA: B(GLASSES & GLOvES) HAZARD MATING: o 1 2 3 4 LEAST SUGHT MODERATE HIGH eXT~eMe ~(CTIQN 1 :lRODUCT NAME~' CHEMICAL IOENTlFICATION: MATERIAL USE: WHM1S Ct.ASSIFICATION: WORK PLACE HAZAAD: PRODI,ICT ICENTIFICATtøN EXTREME NUMBER ONE Accylamide, Acrylate Copolymer Dri!llng Fluid Additive Not Regulated Not AppliGabla T~A.NSPO:lTATIC"1N OF bANG¡;RoLJS GQODS tr.D..G.Bl CLASS I FICA TION: PACKAGE GROUP: CAS NUM8e~: MSDS COO:: No\ Dangerous Gooós Not Applicable Not Applicable N01 ApplÎl:;able SEC'T'ON 2 HAZARDOUS INGREDI&~"1'S INGREDIENT: peRCENTAGE: CAS NUMi3eR: LO (50): LC (50): None Considered Hazardous Not Available Not Available Not Available Not AV'aìlable 10 æ~d e"d Sltfèl3'lIW \1)S\1l\: o.eS"loSe"l.OS eÞ6lZZSLQ6 SZ:Et EQQZ/GE/Gt HQ d~t:£O £0 oe oeij 12/30/2003 18:16 FAX 907 269 8943 . .... ...'W"'" ..."..", ,.,..."".....,"'..,.."..C'1ot EXTRIME PRODUCTS & DR/LUNG SUPPLIES INC. SOA DIV OF OIL & GAS I4J 005/011 . ~~¿~k~~ YKVülL~~ III DQ~ i' \Joø P.AGE ¡Of 5 EXTREME NUMBER ONE IV1ATERIALSAFETV DATA SHEET SECTION 3 APPEARANCE ANO ODOUR: OENSJTY (SPECIFIC GRA V!TY); BOILING POINT; MELïlNG POINT: . SOL.UeULlTY: EVAPORATION. RATE: (EE-1); VAPOUR PRI:SSUAE; (MM HG): VAPOU~ OENSITY: (AIR .1): ~CTION 4 FLASHPOINT: FLAMMABLE UMIT: AUTO IGNITION TEMP: ':X'rINGUISI-IING MEDIA: ~PECIAL FIRE FIGHTING ÞROCEDURES: UNUSUAL FIRE AND eXPLOSlON HAZAROS: SECTION S STABILITY (THÊFiMAl, LIGHT, ETC.): INCOMPATIBILITY (CONDITIONS TO AVOID): HAZARDOUS :)OL YMERlZATION: HAZAROOUS DECOMPOSITION PRODUCTS: £171 ~d ...·d ~I~ tf>l5l;1~ o...ee·lose·loOE; PHYSICAL DATA Slight, mild odour, white. gtanular solid .80 Not Available Not Available Soluble Not Available Not Available Not AvailablE! FIRE: AND F.X:PLOSION Not ,Applicable Not Available No Data Dry Chemica.I, Carbon DioXide. Foarr'J Self-Contained Respirators. F=or Fire Fi9htlng F'etsonnel. Products of incomplete c:ombus1ior. and oxides of nitrogen and carbon. REACTIVITY DATA Stable Strong oxidizing agents and hlgh~ alkaline solutions Will not occur None ØÞ6!ll~LØ6 $Z:£1 EeeZ/DEll! HQ dal:eo eo oe oaa S STORAGe AEOUIREMENTS: WASTE DISPOSAL: SKIN PROTECTION; EYE PAOTECTION: VENTILATION: ..:¡ESP IRA. TORY PROTECTION L.EAK & SPILL PROCEDURE: 'd ÞIa ~cI O.£8·¿S£ S1'l1H3NI¡. 'It)en'C1 ·¿os Impervious gloves. prcteQ!ive clothìng as reQuired Gaggles. General mechanical: 10 changes par hour. Approved dust mask; 'MESA typ'. . Ventilate area. wear rubber boats. gloves and a self-contained resøiratoJ if ventilation ["adequate. Collect into waste contafner. wash site aftér pick up. Watet solutions extremely slippery. Dispose in compliance with govemment regulations and local requirements. Cool. dry area, away from Q)I¡idi~ing ¡¡nc! reducing agents. Keep contaIners closed whel'l not In use. Avoid prolonged contact when handling. Do not ínhale dust 2?6'tZZ!SLIaEi Ha 9t:tt EIa0~/~€/Z,[ d~t:£o £0 DE OiÞa INHALATION: Eve CONTACT: E»B May be minimally irritating to ser.sitive skin upon prolonged direct contact May be minimally irritating to eyes upon t:lirec1 contact May cause Irritation to nOS8 and throat. SK1N CONTACT: ROUTE OF ENTRY: (X) SKIN (X) EYE CONT AC"\" (X) NHALA TION (X) NGESTlON HEA .MATERIAL SAFeTY DATA. SHEET RXTREME PRODUCTS" DRILLING SUPPLIES INC. eX'JREME NUMBER ONE 12/30/2003 18:17 "''''''...,.......",.......,. FAX 907 269 8943 . £....."c:...11: rI\Vli~\'H' SOA DIV OF OIL & GAS . PAGE30F5 IIJ 005 ,'008 141 006/011 12/30/2003 18:17 FAX 907 269 8943 SOA DIV OF OIL & GAS 141 007/011 --.,. -.-.., . . .. ...... .... .--................ ~~.R~~~ r~v~~~AO tCiQOG'O(9 ørREME PRODUOTS , DRILLING SUPPLfES INC. PAGE4 QF 5 EXTReME NUMBER ONE MATERIAL SAFETY DATA SHEET f¡&C'rION'1I SK1N: EYE: 1NHALAiION: , ~'RST AID MEASURES INGESTION: Wash thoroughly with soap and warm water Flush with water for at least 15 mÎl'tutes. Se&k medical attention. Remove to fresh air. if net bre~thing, give artificial respiration. If breathing Is difficult. give oxygen. Seek medlcal attention. Do /jot induce vomiting. If CCMSQCUS. dilute by giving two glasses of water. Seek medical attention. SECTION 9 PRIi!PAAATlON DATE DATE ISS·WED: AUGUSi 20.1996 PRODUCT SAFETY COMMITrEE. BY: . THE DATA REPRESeNTED HEREIN IS BELIEVED ACCURATe AND REFLECTS OUR eeST PROFESSIONAL JUDGMENT. HOWEVER, NO WARRANTY OF MERCHANTABILITY, FiTNESS FOR ANY USE OR ANY OTIoiER WARRANTY IS EXÞAESSED OA IMPUED REGARDING THE ACCURACY OF SUCH DATA, THe RESULTS:O BE OBTAINEO FROM THE USE THEREOF, OR THAT ANY SUCH USE DoES NOT INFRINGE ANY PATENT. SINCE THE INFORMATION CONTAINeo HEREIN MAY BE APPLIED UNDER CONDITIONS a.F use BEYOND OUR CONTROL. AND WITH WHICH WE MA V BE UNFAMILIAR, WE DO NOT ASSUME ANY RESPONSIBtUTV FOR THE. RESULTS OF SUCH APPLICATION. THIS \NFORMATtON IS FUANlsHeD UPON THe CONDITION THAT THE PERSON RECEIVING IT SHALL MAKE HIS OWN DETERMINATION OF THE SUITABILITY OF THE MATERIAL FOR HIS PARTICULAR PURPOSE. DATE REVISED: S0 39\fd sod S~3>lIW t'~~ O"Eso¿SEo¿OB ØÞ61~ZSL96 Sl:E1 £0Ø~/g€/~t HO dat=EO EO OE oeo 12/30/2003 18:17 FAX 907 269 8943 SOA DIV OF OIL & GAS I4J 008/011 ---.".. ~ ...._~- . -e ...- - - -_.~ SECTION' 0 ECQJ-OGIOAL INFORMATION II,JU7I:UU"I - :;0 I:. ¡;- .:I~ . PAl.e 5.~Qf I ii, ~, EXTREME NUMBER ÒNE ~. "¡'. ì· t ';:: ~t' ..~:\ 11~~ t &: }1.f. LDSD/oral/rat > 5000 mg/kg : '" : f' The results of lab testing showed tram m1' -riaìt~ be noMoxic even at high dose levels. ." r ';¡;, , " .- The Pf~duct is not exøected to be tox~ bl;' ':J Inhalation. : ' 'I ':.~ :~,,",L, . . .': f. The results of Jab testing &hOwe~ tl1ls.m~ñal]o be nonwifrnating to the skin. . . !: :t Testing conducted ~cofding to the Dralz,' 2: technique showed the material prodLlces~'D ..~~: ~ .' comeal or IridIal effects and only slight transitory r::anjllncti\Jal Eltfect$ similar 10 those which!'-. . granular materials have no conjuctlvae. . t ,: The results ~f.lab testing shoWed thi$ matinal ~p be non·sensltlzing. . ~~ .', The reiul1S of extensive lab testing did ncifrev~ adverse t"lealth effects, 'f-: " :~ '. '\", ~;~. :ti :., ;".., LC50 ¡ F~thead minnows J 96 hours > 1~ m~1 EC50 I Selenastrum capricornutum )00 96 ,urs ,? SOO mgfl :¡y;, f The prodl.lct is not expected to Dioaccum1: ~te;1.; Not readily biodegradable. ~ .... .~ . '1\. t: .' . .'" , ,.. .? ,~. ". OJ ,·18,'01 15:~1 F~X ØO~S3S5~oa t.\'! Hb.:I11: I'NUl.I'.I<.:l'S EXTREME PRODUCTS' DRII..&.ING SUPPL.IES tNC. MATERIAL SAFETY OATA SHEET ADDENDUM ACUTE TOXICITY: · ,-Oral: · Dermal: · Inl'1alatlon: IRRITATION: · Skin: Eyes: SENSITIZA rION: CHRONIC TOXICITY: ~QOTQXICITY . Fish: - Algae: 8ioaccumulation: . PersiStel'lce I degra.dability: ,~:~" ~1' :.""- ".. ., ·t.- -'. ¡'~~ , .' ., " J> '30 39\fd l.'d 51\fd.)'IW 'i:I)S\1~ OÞ£B'l.S£'l.DS ~.;. ...., ~.t;!.'. .... '" ~~, I'· :~~. .;~ ii' t~;··. J. 9Þ6t~~Le6 Çt:E1 £99~/9E/~t Hcr d£l=£O EO DE oacr 12/30/2003 18:17 FAX 907 269 8943 SOA DIV OF OIL & GAS ~ 009/011 . .- .~.¡r¡¡.:_: ~: ":::~k ~~':~ '. ..:: ,:. ..~ .. .., .' .. :",'j;\ ·~":·r ~"~';' £'.::. :'J-.:":' t ," _ .. .~.,,~~~ :~7~~.; ';':~': :":; ,;;;:;:~~ .:';~:!~.:. ..;¡~f...;, a¡;,.,:...... ..r. . ..._,....... . ......,....UU,nl.. rh...e.... .rfnf ..... . .r..... . ....,.... .. MAnaJAl.SA.FBTY DAl'A SIal' Moy bnllld WillIJDI!J..íIhOSlfA'IIf.wdCaIII_II"'_a:llliAdIri. ~CRt 1011).1200. SIaIIduØ_t bcctlll>UlWo141t«¡l~t~_ PRODUCT NAME~ SUPD GiL-JenI Sectio. I MANUFACT1JRER'S lNFOa."iATION MANUfACTIJR£R'$ NAME.It. ADDRESS: 0.11I pr.red: J..... t. ~ 691(11169101 h~hn caco - fhillin, """t:Ì5 c;,.tItIp relepbeDt NIIJnÞer': 147-:Ø2.,SlIIO I'u 11474U.61st 1SOO Wcat SIIIIft Dray. £Ml.RCENCY CONTACf: Cll£M1"R"'C 8tO-42...93Ot Arll_øe- HeiCIlà, IL øee4 ~ W_.CIttH,CQID Settionl1 8AZABD01JS INGREDIENI'SllDI.NTl1'Y INi'ORMA TION I.L\ZARDOUS COMrON£NTS: 0Jtier Lln\itII. (SJ*Üic ChtmicalIdeDtil)': Common 1'I-.e(S» OSHA. PE\.. ACGIH TLV ~-IIU11l:lllW Çi'ysealli...OIWCZ: CASt &4101-60-1 II Relpin=:~rrœ 0.' m~' s8:A=J 5~~ N.illua ~ Rtspitllblo S mlV~ S DllfnT1 ToIII DUllt 15 mp' 10 mglm~ ~ W ARNlNG: 1'Iti:l pEOduCl coluam. . sml1lllntOl.lnt of cr)'sualliRc lliIiGA1.'!h1ch MaY _II cIe1aye4 resDln!OlY distllle If iDhIùcd over a protonae4 periõd af timI:. Avoic[ breatbinC dl8St Use NIOSHlMSnI\ ~lIédB' wflcœ 'Tt V for my_ilIAC $ita (OUlll'tit) ~ lie c~ tARC MOIIOS~ QJ\ the cv~til)Cl of !be Cuciõa:iacsúc of Cl.la:aiatlll 10 HIIDWI6 (voJilmlo 68. 1997) c:ãadüdC6 IiIM ~11iJw silÎclII is CltclÏlosellÏc to hUIDIIIIII io the fGma or qU1llfL IAIt dai5Ïr~Oß J. '('he sowl ~_ 01 c~lUne silica (<IIWIZ) faww! in thi~ DCOC1uct are IIIIdIIr acmnaI «mditiollll, 1UIUIraIly c:oeted with an unRlPDWb1e l!I.I,cr of ~ sili.CII udfot btlllOnite clay. IARC (vøl. 61. 1997, !If.l!n-191) 1m ~iaIçd that crystalliuc Iiitiesi (q,IIaIÙ) 1:11\ diftèr in \l)lLic¡ty d"))!mdin~ 1)1\ die mmeals Wl.1h which it is. combiDed. CI 5tud1eS in IARC (yol. 42, 1917, P. B6) wbic:h stared that the lo~i.c dfed of cryál.line iilica (qÞUtZ) is lCduced by the "protecli~ cct...due maill'Y to èlay mìDCnlb...' NaCÏItMIlnadÞlIC for Ocs:llpatitt... SsfetJ .d ...th (NtOSM) bas ncollllJR:l\4ed dlat die pIG1IIiüiblc CIrpOSurc limit be çbanpl 10 SO miOf08l'8lll$ respirable &~ sillc. pea- ClJbic: mcœc of air (O.OS mtJ af) as determined by a t\Ill sJlilt 81Ø11Ple UI to a 10 hoIU war:kiag day. 40 bollJ1í per w=k. St!!: 1!174 NIOSH Cl'ÎICl'ia (or. m:omme~d Standani t'orOcc:upationaJ ExpoSW'C to C~Ia(1.iDc Silio. _utcl be CIOßSUlted Cor man: _iled informaÛW1, PEL· OSHA PetlÞi&siblc 'Expoll1Ø Limit. TLV - Amcric:an CoufemIICC of Oovemmenta' IacIlIS1lÌal HysÎelli~ (ACGIH) 1'hresbo1d LimiL V61.ae. TW A . 8111>11I' 1ime weighted ¥\It'$&" Not4l: The P\.-nDW:ible eQosure Limits (PEL) report¡:d llbùvc ItC the ¡IN' 191191imilS _ we" n:instated by OSHA. JUDe 30. 19!n tòllowing a tkCÌlliOll by Ute United S~ Circuit Court of Apþeal5 Cor 1bc 11 dI Circuit. Fs:dcraJ OSHA ia IMM Wòtcinslbcsc PELs. More n=ictivç =ApOSUre limns lOlIy be mfarced by .some 0_ jUÑdiélÎOns. PROOUcr mENTlllCA1'IO~: Claemical NUIIIr- Dry Mixt\lre oflmKgaRic Minlll'lll CompoUf\d$. NFl AltlMI$: Healtb - 2. F'~ - 0, RcIC\ivKy - 0, Spl!Cifiu Ha2ard . Sea SectìoIJ /II. SIIÏ1II!- crus: Not llcKutldèd (DOT I 49CPR., lMOO.1CAO I lATA). Set.... UI PHYSICAUC8IMJCAL CIfAKACTERlSTICS iCl11bIC PIÛC No' AppliCllblc. Speüiç Gravlt)l ~ - I): 2.5 Vapor ......rc (ØllJI Kg,): Not Applicltlk. ftttcltiag Poiah 1400"F Vapor Density (AIR '" 1): Not AJlplicablt, ¡:YMporldoRR.ate (BI4\yt ACCIata .. 1): Noc Applù:¡¡blc. SoIullilityiR Water: N¢8Iilible. Ap(lellraQtc .n4Odor~ T"'Of\loisoUlJiþ~eolG"'ICI.....¡orlllC\lJllIlllb.~ % (Mdnna.l\ <6% <2% ISOOW. Sbwc D,'., ArI~II\lÌßlua. nbDllb60004 USA I +11IIIO.Sn.994/leI+11I41.3i2.S8ODJrIlX. ',1 $47.57'1.ml CCp)'ri¡bl200'2 CE'CCO All rip.. &a-.L œTCO oaa ....1IoIH1 .... tuboûIialy Q( AMC01. ~_I CalP. sø 39Vd S'a! S~è!GIIN 11>91~ OY£S'loSe'loOB eÞ61~~SLeG st:tt £e0Z/9€/lt Hcr dEt=eO EO DE oeo 60 S'd 39\1=1 0..,£8 1500 w. SblltC Dr., ÑlinafD KDit:h~ QIÍ/lQI16UCJ04 USA I +1 loo.s27.0I48 1 tel +1147,392,$100 I........¡.I IdU77.ßl1 CGp)llIIL2002 C£TCO An ,iþ -- (:ETCO b a .Uy ,,_d ..MlÏUy of AMCOL IøllltlIIIlouI Corp. '£.5£ S~IN t!)S:f1I¡I '¿OS 0Þ6të;<:;SL06 H(I S(;:€t E00ë;¡Ð£/Gt d£I:£O EO Oe: OiÞ(I !.i. Clan D, Divisloll 2. Subdi",istoll A. cyr,r¡ To Hatd!: 2. Fir$: C R.eeclivll)': 0 Heald!: .. F¡": 0 ltøl.1.ivii)': 0 "'WIt.lalC: . CluaaW beahh eftÎ:(;t possible - inha1atioD of silica dust may C&1aO luna iajury/diseaso IllØlildS U) avoid brc:albing dœII, SiNe Sectlrm 11. RUE"ØNCES: bei&cry £or Toxic 'EtTlnIlII of a~CIIl Subs1AftCCa (RTI!CS), 1995. Pauy'S ll1cillslrial Hygiene and To,iI:DI~. N''P S~venth Annual Repod on CllcÌIIOgaI$. 1994. !ARC MOIIog:aph Volumu 68. Silica. Some Silk" lilieS OEJCUIÎo Jljben¡, 1997. ne tlllorlD1l~a ..... Iw .... eoøpiW fro.. .an. ~M to be lI'I!lbbIe .... D acørat. .. tile II. ef 4t.. kDo~lcdp. HD_VèI'. mOO ~ll.Ilaot ..... ..y IUI'IIIICe&Ii ....nli..Z itaf_....... fn. __ 58IU'CIS, alUl eqltellllJy ...... aøt ..tile .." _lU"randell. .. ....mDIIft)' 1IIIJÞiIity. ror ÜI -. (sllii:l>8Ïs). TIIkë GpplopßalC on Law. me ElNECS C~røb i ,1 '[J,Ï$ product ,'On/o;tU lite P!lIðWing $ùbSltlnc,.. known 10 the .sUITS oJ ~/i4 to ClllØe riMt" and/or " clive lID",,; ¡Hod¥cJ œntDills t:tyffollilr. siliCtJ (respirable): MWCIIU. #he IØIÌt' lJIGulrJ no/It thul rhe 1IIfØI{ qaunÞlíØ$ of. t:T¥rlllfn", .fi/1Ga (quDI'I=I. þnld in Ulø ~ aN, undllT I/fJI1JIlI Conditions. 1ItIlIIrai1¥ f;Q{IIt:d with Ø1I røtnmøvaÞl. løl!' õf QII'IO'IIIrøu¡'lifi", "ri'ndIGr fiërtJu"i~ cl~. UR.C (roL tJ8. 199'1..px. 191-191J bœ J/ltlted rlial tJ~ùfljlle ~ilic:u (qlJaru) c:mI J~ ¡If w"iclly d,,~n4.im: ø,. rb.! mineTUls with which Ü IS combfMd, Cjl¡¡r,~. m rARC rrøl. 42. J flB'1. e· 16) ",hlcJt SteKeillhlJJ díé r_~ 1/ftIL'I 01 ~llIItlìie sfliœ (qw.¡rW j, redlÞd by tN: "pr(JtlCfive 4ÞCI....due ",.lily liD clIly ",¡"e,rJis... " A.U of Ihe Dr this ,1'Oduct arc tiMed ell' .. EPA TSCA mwnllJly ot art exempt Iiom 'RODUCT NAME: SUPER GItL-FM SeeCiOD vm CONTR.OL MEASURES Røpintor)' PreteeCioÞ: \Jse apploprilM l.'C$piracmy prow:IÎOø for m.pinbte ~Iate baa on ~:¡;;~idotlll¡on of ~ wurkplac:; çoøçeAIIation aDd duratiòb of eJCPCI'lft wÌDI from imended ... IlK. RJcr to. most ßICCQI. Sl8llWds at ANSI (zl8.2) OSHA (29 CfR 1910.134), MSHA (30C~lt Pad$ Shnd S1) aød NIOSH Rc:spùalø' Dcçislon LoP:. Vcadl.1IGa: Use 101;1& c:xÞau¡t 11II r1quiIed 10 maåatain I:KputltØS ""low appll.cablo oewp¡¡!i()ßalOItpcSIUC iimilS (SIIe kilo" II). see also ACGIH ·ladli&triat VenliJltioll- A MBnUaI t'orllecommc:nd Pmclb", (curMII eåùÏCnl), Pntecth-. CloY.': Not R.equirocL EYII P........; ~adDd. OtJallr PrOCllCllVt CllJtllilllll. Dr Equip.eat: Nalle. W..klHY2lenlc 'rr"a: U!lC: r.øod ~ ÐtDCCiCCS. SectiOD IX REGULA.TORY lNFORMA'rlON _312: HazKd Caœpc:s fot SARA Sedioo 3] 11312 ltepDl'Ûl1I: Chronic: t1ea1da . ~ 11Iis product conïi&lDlõ die followin¡ chemicals 5aaDject to IUItIÍIIIJ n:lease reponing ICll.ui~ uzuter ÜJc SARA sectiocl I'K '72): NOM Cf:atCLA . NoIIC IIrfll'..u 11M'.' ,j"'" 12Z30/2003 18:17 . " ,::'..;~~-:."';: FAX 907 269 .. '1; ~. " nl.~f 8943 . ~:. ;:. ..~ SOA DIV OF OIL & GAS . 6910L/69101 ,ago 3 on 141 010/011 12/30/2003 18:18 FAX 907 269 8943 SOA DIV OF OIL & GAS I{! 011/011 . . ,"1 :~:::? ::~;'" ~__:~~: ...!;~ t·..·~.\ _,. ......... _ \~:t.·~~.r';.-- _..~. 'V'': !7J!:-~:~~~:~ .~~~ :~! ' .~;~~:'~~i':~' ~." '~~;r;"": <?t,'t). ," ,__.... ..,.. .;.~,~ ~,., ,1, .,.. " , .. .., . .. ,.... '. .~. .~,.:~,~~"., ,,':' ..: - .: ; ';' 0' :.: ,.' _; ~.' ", " ,......... ~ ..·..,at ,. a.al.." . .41.,..... . ._!lflt".. . ..,/tIf'.....Ucc..d.. Ca..,.ur.r. , .". '",':",,',:', 'J~~~"'¡"~::~; ~:::;. ~;~~ . .... . I:~j~ . .. .. .rfll f. ",nd.. .,o.ea "101/69101 Page2Dr3 PRODUCT NAME~ SUPER GEL-XJI'C Slttio.tv FIRE AND EXPLOSION ~ DATA naØ PcItIIt (Melhød Uud): NoL AvaUable. ......... Ullliti;: 1'101 A.nilablB. J..'f.L - !'IA. ua. - NA. E:llÜapWlbI& Media: Not Applicable. SpedM iô'in FIptiIt& Premtu.rc: Not Applic:able. UDolllal fin/Es.....lføarch: PrudllCf may DC!!IC uo.i.bIè dldt cxøIoaiaD lIIICWen...mMi nn'fI circ:unn\}1!~!llJr COØI1ìtions, Sect'" V REAClIV1'tY DATA St1Ibnity: ~Ie CGlldldolll to ¡\vÞI ~ Noae Known. I_~ (Møreriøls 10 AYOitJ): Powcrfu.1 olCidi'Ztll8 apnlli aIICItI a$ 1IBorine, ch10rØ uif'luaridc, .....IIA'* 1rio&Ï4.:. C*, Ruard8us 'DcCOIIIpasitiøa 81' 8y-produdJ¡¡ Siiica will_oly,: ¡" lIydrDf\uoric: 1lCi4 ."odudUSIi c:ùR'QSivo: JIIS. sWwll tGlraß~. ø.......J P8hnII:rioIÏO-= Will Not Oecur c..dido-. Avoid - Not!ç"KJ1own. Section VI HEALTH H.AZARD DATA ..e(I) or £aU)': Inhala.tioa'/ Y C$ Skin? No HnIdi ø-;a" (At\lte u' C.....IÙC:): lallld.U..: BröthÏI!.ß siÜI:II duSt IWI)' lIat !:&\tiC aociceab1e iNury or illMss eyeD thoIaeh peallllMn' lIIIIS cWmBC: ØlØY be occwring. IlIbabUÌOQ of ÒlJ5.t nœy have lIIe folOVllÏDgliOlÌOus cbí'øIiC laoat1:h effecÞ: SUIco&iII: ~øi"t: ildmlation of relilpiølblc çrysllATlillli: saica dust 1_)' cause a ~p:llSiY" CÜUl)UØI IIIUI iOlnetllUCll-fIdaI lung WIICIISC callc4 silic:o:lÎ6. Sy¡aptøßD iatLudC ~ $bln'UllOS5 ofbImb. wttocžmg; DOßoIlpeeök: chest illnc&& - œdud 1!91mo~ Wncùoø. Smoking eøccrbata¡ thi6 disease- lDdi...idu&Is Wit1Isilico1;i6 i\Ie pnd~1:d 1(1 devc1aD tubcfalLosis. c.ccr /itabŒ The ~ÓDaIl A~r fòr R.eselCdl CD ClIICCf b8$ ~ dild ~1ÌJ1c sJ}ica lnbalccl ín c.bc (ann or ullU or ari:ltøb¥liœ (rom œ¡."'P'lioUl soLlP:Cli i6 c' 'c \0 II~ (Grpup I - ~~c to 1wmtAS), Refer to C ~ ~jc Sir 1I!.t d . (publiåcd 10 .hailS 1991) ÌII ~ioII wilh me IdI of e materiaIL The Na!iQllal ToxicoloJY ~m cla:isÎfil:S RSPItJbIe ~Lioe sìJica lIS '''rCaS0111Ib1y G!\I~ 10 be a cafCînoJe1.!". For rustÞer int'.omJ,IIlOf) Sß "Adverse cffCC4S or ~tã'I'IiM Silica ~.. publ__ by die AmcricIn 'Ibomlo'1C Society Mçetical Section of dieAøa:riœD LW\C Aøaciadon. A.mcriI:aß ]ouriial of R.esplrAtOry alÜ CritÍGIIl Coro Medicine, VolUIIIC IS5, page 71\1-765. 1997. Other Data willi possihle Relevø,,:e tv IWmaD Høkb.: The SI1UII\ nuaetiôes of crysratUol!Isilic:a (!luartz', found iø tbiIi DJ:Vd1lCt an:, ÓI\dCr 1IOIDIII1 coødirions. _tural~ coMGd with lID ~VabIC hty~,;¡f amo~ $1 ica aødlot lierlUmìu: daY· IAllt <Vol 68. 1997. P& 191-192) has I1III1Cd IMI GmIa1'IiP~ siU~ Quartz) CIIII diU'èt ia tœicil~ ~ OR tM mia_rab willi wlÜcb it ÌIi comblWl, ciÙl!¥ sWdies iD (AIlC (Vol. 42. 1987 PI: ) wbicR sll&tcd Chat die roxic effeø or ctyllmlliDe siliw (quartz) j,¡ teducec1 by the "pro~tive ii'tm,~.cW.lMinly to day mincrals...- lnpIItion? No C",.eCellidl)'1 SigIlli and Sy..,ÞnIa!I of £Qe_e: &ccssive iÐba1l1Îon of pneraœd du'L may resv.lt in åortMSS of bceGlIt:&ll4 raduced puldlO"" function. NTP'r No ¡ARC Moaograph1ì'l Ye$ OSHA.llCþI.? No Medical C..ditiou Ceacrll1]l AØRvued. by £1IpOll.....: IlUIividua18 with JeIIpÌrIØOI'Y --. iocludinlt b..a not limited 'a, \IiIIUIV& and brOm:bitå&, 01" M\bjecl to ¢'jc Ì1titation ~uk1 Rot be ~ 10 rcs.pirab1e ~\i... .wee (qtIIIIti:) dll$t· ElRuJ:CIIC,- fint.Aid Procedw'iS: Eye& a: Skin; Flush with WlUet. (¡TOSS iøbalålWn of Dust: Rcmo"''' Lo fl'C$h air¡ ~ OX)'JCII or artUicial ~ if~; &cek medical IUCII1Ion. ltUl.eStion: lf1~e aDI(IIIgL$ are swaUawed. get iØID~ mediaL! I~' Section VII PRECAUTIONS FOR. SAFE HANDLING AND USE. SI. 10 be TakeQ Ia eM" Material II Itd"a- or $pil1ud: VIICUUII\. ii' pOssibic tþ avoid gcaerøtíog aiJborG& dull&. Avoid brcatÞiD& du:n. wø-aupprovcdn."IIpil1ltor. Avoid addiDl water; prodllCl wilt bcçomulipp«Y wheD wet. Wal' Pifttoal Metllod: BUI)' in III IIpproved 1llllÍW)' ImelIiU. in aceon1aACe willi. f.cder81. s\llD= aDd goal A!i¡u1ations. 't'eI:8t1d9.' to all TaIrØ Ia Haadtinc and StoriDF Avoid brcatbin& duSt, \ISØ Nl0SHlMSHA approved. respiralOr whøre 1'L V 1\miII¡ Iw Crystabim: Si~ may be excc~· Other PrecnÜO-: Sti)Pery whel'l wet. I.5òOW.Sb.wc Dr. Aòin~odloi8'l&, Øim)is60004 USA {+t IICO.S:t7.9MII/LII +1 "'7,392,5aaoJru'~ 1<I'.S71,5571 C&1p)"flllt 2b02 cp.TCO AD ti8f'U .-..a4. cnco ioIlI wlWDy a_II _mÌIrY Gr ...MCOL blllmlllJaaDl Curp. _. ,at 39';1d o ¡ -... 5-W~3'lIW tI>t~1\1 Ot7e:B'l.Se:·l.OS 9Þ6t~ZSLB6 S~:Et E9aZ/Ð£IZt Ha de¡:eo eo OE Qaa . . FRANK H. MURKOWSKI, GOVERNOR AlfASIiA OIL AND GAS CONSERVATION COMMISSION Shane Gagliardi Petroleum Engineer Evergreen Resources (Alaska), Corp. PO Box 871845 Wasilla, AK 99687 333 W. 7'" AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Kashwitna Lake #1 Evergreen Resources (Alaska), Corp. Permit No: 203-209 Surface Location: 1847' FNL and 2050' FEL, Sec. 7, T20N, R4W, SM Bottomhole Location: 1847' FNL and 2050' FEL, Sec. 7, T20N, R4W, SM Dear Mr. Gagliardi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this.Lf day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA .' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 /N'GI\- 11../1 fl1.oo~ C6{> riftp 1 a. Type of Work: DrilllZ! Redrill D 1 b. Current Well Class: ExploratoryD Development Oil 0 Multiple Zone D Re-entry D Stratigraphic Test 181 Service 0 Development GasO Single ZoneD 2. Operator 5. Bond; IZ!Blanket DSingle Well 11. Well Name and Number: Name: Evergreen Resources (Alaska) Corp. Bond No. RLBOO03430 Kashwitna Lake #1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 871845, Wasilla, AK 99687 MD: 3000 ft TVD: 3000 ft Wildcat 4a. Location of Well (Governmental Section): 7. Property Designation: Sec 7, TWN 20N, Rng 4W State of Alaska Surface: 1847' FNL and 2050' FWL 8. Land Use Permit: 13. Approximate Top of Productive ADL 389316 Spud Date: 10 Dec 03 Horizon: Same as above 9. Acres in Property: 14. Distance to Total Depth: Same as above 108 acres Nearest Property: 560 feet 4b. Location of Well (State Base Plane Coordinates): NAD 83 10. KB Elevation 15. Distance to Nearest Surface: x- 1627777.26 y- 2865814.36 Zone- 4 (Height above GL): 195.3 feet Well within Pool: 76,560 feet 16. Deviated Wells: N/A 17. Anticipated Pressure (sej 20 AAC 25.035) ~ ~fi~~ Kickoff Depth: N/A ft. Maximum Hole Angle: N/A Max. Downhole Pressure:- sig, Max.Surface Pressure:' sig. 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including Stage Data) 6 4.5 10.8 LP LP 200 0 0 204 204 17.1 cu. Ft. 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD(ft): Plugs (measured): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments: Filing Fee 181 BOP Sketch IZI Drilling Program IZI Time v. Depth Plot 0 Shallow Hazard Analysis 0 Property Plat[8J Diverter SketchO . Seabed ReportO Drilling Fluid program[8J 20 AAC 25.050 Requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane GaQliardi Printed Name Shane Gaaliardi Title Petroleum EnQineer Signature 4 ~_ðY Phone 907-355-8569 Date j2./¢..3 (/ Commission Use Only Permit to Drill q I API Number: zoJoC; 6:~~it APproval tJ I~JO~ See cover letter for Number: /r)< --2.0 50- ;2 <6 :3 ..- other requirements. Conditions of approval: Samples requirecj ~Yes .ONo Mud log required. 181 Yes DNo ¡¿ te h, ~rogen sulfide meascts DYes ~NO. I Directional survey requirecj DYes J8No Other: .; e:-.t C\; ~-e.J ~ 'Pt-11 <;.. " . J\..pf~ 0 V tl. . RE("';¡::J I -JI ) ~ ..---,00- J} ~I BY ORDER OF Da¥Fii-tl~ L ~ ~ 7 Approved by: /~ .A. MISSIONER THE COMMISSION Form 10-401 ~ised :3 003 U!;;.\" iJ' l ~ ,"it hi duplicate Core Pro ram 2003 APD . Commission WGIt- g OR\G\NAL Alaska 011 & Gas Cons Anchorage Dee 05 03 05:56p DH. NOTES: 1. COORDINAlES SHOWN ARE NAD 8.3 ALASKA STATE PLANE ZONE 4 BASED ON PROTRAClED VALUES. 2. GEOGRAPHIC COORDlN A l'ES ARE NAfJ 83 BASED ON PROTRAC1ED VALUES. 3, ALL DISTANCES ARE GRDUND IN U.S. SURVEY FEET. 4. VERl1CAL DA lU~ IS BASED ON NGS CONTROL BENCHMARK N-1Q4.. EL "" 222.22.' KASHWllNA LAKE #1 LOCAlED 1841 fRO~ '!HE NORlH UNE Of SECTION 7 AND 2050' FRaI.! THE I'IEST LINE OF SECTION 7 T 20 N, R i- W, SEV/ARD MERI()AN AT LAT. 61'50'~7,03(}"N LONG. 150't)4.'23.362"W ÞS> ZONE 4 N=2ß65814.:S6 E=1627777.26 (NAD BJ) GROUND ELEVATION ~ 195.3' N I 6 COMPUTED POSIllON 12 7 SCALE 1- = 600' '.., ,.... rD 5 'Q" SECTION 7 T20N. R4W, S.M. ALASKA FE n: c :z: MC 7 KASHWITNA LAKE #1 PERMIT DRAWING DRA'M'I KWA CHECKED KWA SCALE l' :::: 600' ~ iE 907.357.8340 e p.4 13 THIS PERIoIIT 12 N -+ 17 .. /, ! VICINTY MAP SCALE ," = T20N MILE 1/4 6 N 89'50'.34" E 226B.62,' 2049.81' 7 'in I.() <D ~ co - Kashwitna La ke #1 ~\ -0 ~ 'fJ, ~ \ ~ r@LOUNSBURY & ASSOCIATES, INC. SURVEYORS-ENGiNEERS-PLANNERS . 723 W. 5th AVE. ANCHORAGE, ALASKA 99501 (907) 272-5451 FAX (907) 272-9065 December 04. 2003 DWG NAME 03-0Jl-5.DWG ~roposed Drilling procedure- Core Program 2003 Matanuska-Susitna Borough, Alaska Objective The objective of this operation is to core the intended wells for geologic study to determine coal bed methane exploration potential and begin to describe the Mat Su Basin Casing Program Surface casing will be run from surface through the glacial gravels to protect fresh water. The surface hole will be 6 inch d rf' iameter and the su ace casinO will be X-42 4 inch nominal schedule 40 line pipe. Hole Size Casing Size Casing Weight Casing Casing Approx Casing Cement (in) OD (in) (Ibs/ft) Grade Connection Depth Interval (ft) Surface 6 4.5 10.8 LP LP 200 to surface Mud Program Water will be the primary drilling fluid used. Bentonite and EZ-Mud DP or other fresh water polymer may be used if hole conditions warrant. After the well has reached TO, this mud will be conditioned and transported to the next site. The cuttings will be tested and either spread on location, sent to an off site disposal facility or placed back in the hole as part of the abandoning process. Open Hole Logging Program Memory tools will be latched into the landing sub above the core barrel. The hole will be logged as the drill pipe is being pulled out of the hole. Log Interval Single Induction TO to ± 20 ft in Surface Casing Sonic Porosity TO to ± 20 ft in Surface CasinQ Gamma Ray TO tot 20 ft in Surface Casing Caliper TO to ± 20 ft in Surface Casino Compensated Density TO to ± 20 ft in Surface Casing Neutron Porosity TO to ± 20 ft in Surface Casing Formation Tops Formation Estimated Tops (ft KB) Quarternary Gravel Surface Tertiary Tyonek 50-200 General Information All information not publicly available is considered Tight Hole and confidential. Spill Prevention Plan and Bear Mitigation measures must be adhered to at all times. Core Program 2003 APD e . Proposed Drilling Procedure Core Program 2003 Matanuska-Susitna Borough, Alaska SURFACE AND CORE HOLE 1. MIRU DJ excavation. Make any necessary changes to location to accommodate core drilling rig. a. Dig 6' cellar wI 6' diameter and place culverts. 2. MIRU Discovery Drilling. 3. Drill 6" hole through base of gravel (50'-200' anticipated) and set 4" casing to bottom. a. Evergreen personnel will call TD on surface hole. 4. Cement casing in place wI 1-3 bbl cmt wI cmt wt @ 15.6 ppg a. Water requirements - 5.2 gallsk b. Slurry volume - 1.18 cu ftIsk c. Leave 1" to 2" of cement in cellar for seal 5. RDMO Discovery drilling to next well. 6. MIRU Layne Christiansen CS 4000 core drilling rig. 7. Fill mud tanks wI city water. Make sure there is enough mud on site to mix kill wt mud if necessary. 8. WOC for 6 hours. 9. NU and test BOP. 10. Pressure test casing to 1500 psi. 11. Drill cmt and csg shoe. Drill 20 feet into new formation and POOH. 12. RIH with HQ core bit and barrel. 13. Core to Arkose Ridge formation. The well will be TD'd above this level if significant hole problems occur. a. Arkose Ridge formation: Fluvitile and alluvial feldsparic sandstone, conglomerate, siltsone and shale containing abundant plant fragments. b. The core will be described on site by Evergreen personnel or contractors in the following manner: i. Apparent texture variations 1. Fractures 2. Bedding plane attitudes ii. Apparent fluid variations 1. Presence of hydrocarbons iii. Apparent lithologic variations 1. Rock type 2. Porosity 3. Sedimentary structure 4. Grain size 14. Evergreen personnel will call final TD. POOH wI last core inner tube. 15. Condition hole. 16. PU 30 ft off of bottom to make room for logging tools. 17. MIRU Reeves Wireline. Drop memory tools consisting of Gamma Ray, Sonic Porosity, Array Induction, Compensated Neutron Density and Caliper. 18. POOH and LD drill pipe, rods, core barrel and core bit and logging tools. 19. TIH wI "B" rods to TD. (Cmt calculations are based on TD=2500' and surface csg @ 200') a. Surface casing - (0.01574bblslft)(200') = 3.14 bbls b. HQ Hole - (0.01440 bbls/ft)(2300') = 33.12 bbls c. Total fluid required to fill hole - 36.26 bbls 20. Pump 3 bbls cmt and POOH 210 ft. 21. Pump 18 bbls (1250ft) of mud and cuttings and POOH to 1000 ft. 22. Pump 15.1 bbls cmt 23. POOH wI liB" rods. 24. Clean-up well site. 25. RDMO Layne Christianson to next hole. 26. WOC 24 hours. II t. 1.. yJGk 27. MIRU DJ Excavation. ~ I ~ (JA.(À.wJ:\ev a. Cut 4" casing 3' below ginal ground level. b. Weld ~" thick plate wI. Cliameter onto 4" casing. c. Plate must have the following bead welded information: i. Evergreen Resources ii. Permit to drill number (Number will be provided as soon as it is issued by AOGCC) Core Program 2003 APD iii. Well numb_ e iv. API number (Number will be provided as soon as it is issued by AOGCC) d. Remove culvert and back fill cellar. 28. ROMO OJ Excavation. Core Program 2003 APD e Proposed Drilling Procedure - Core Program 2003 Matanuska-Susitna Borough, Alaska Core Hole Diagram 6" Hole to ± 100' 4" LP (4.5" aD, 4;026" to, 3320 psi) @ ± 200' Cemented wI 25 sx Portland cmt r·..·...·'·-··' " Tyonek Formation Arkn!;!! Ridne FnrmRtinn HQ Diameter Hole (3.850") to 1800' 2.5" core. Log hole using memory tools latched into landing sub while pulling drill pipe. Rig Layout Diagram II' 9' 23' Core Solids Drill Control Van 40' 20' Core Handling Rods - D Parts Trailer Water Truck De-Qasser Vehicle Parking 60' .. 45' . Core Program 2003 APD e e a nus a- USI na orougl , as a Company Address Name Telephone Evergreen Resources Inc. Suite 1200 Dennis Carlton Office: 303-298-8100 1401 Seventeenth Street Senior Vice President of Fax: 303-298-7800 Denver, Colorado 80202 Operations Evergreen Resources Inc. Suite 1200' Scott Zimmerman Office: 303-298-8100 1401 Seventeenth Street Vice President of Operations Cell: 303-981-3314 Denver, Colorado 80202 and Engineering Fax: 303-298-7800 Evergreen Resources Alaska P.O. Box 871845 Shane Gagliardi Office: 907-357-8130 Wasilla, AK 99687 AK Project Engineer Cell: 907-355-8569 Fax: 907-357-8340 Evergreen Resources Alaska P.O. Box 871845 Mike Bellowich Office: 907-357-8130 Wasilla, AK 99687 AK Project Geologist Cell: 907-232-9538 Fax: 907-357-8340 Evergreen Resources Inc. Suite 1200 Jerry Jacobs Office: 303-298-8100 1401 Seventeenth Street Environmental Manager Fax: 303-298-7800 Denver, Colorado 80202 Hampton & Waechter Suite 300 Noel Waechter Office: 303-825-7140 1645 Court PI. Denver, Colorado 80202 Layne Christiansen 2370 Steese Hwy. Shane Crum Office:918-322-3095 Fairbanks, AK 99712 Mobil 918-625-1668 Fax: 918-322-3829 MI Swaco 721 West 1st Ave. Dennis Jackson Office: 907-274-5501 Anchorage, AK 99501 Reeves Wireline 121 South Country Estates Bob Gales Office: 785-331-2933 Road, Liberal, KS 67901 Proposed Telephone Contact List Core Program 2003 M ta k S "t B h AI k Core Program 2003 APD Manufacturer: Size: Rating: Usage: e e Well Control Diagrams Core Program 2003 Matanuska-Susitna Borough, Alaska Cavins Oil Well Tools 4" 3000 psi Used for mineral exploration core drilling in Nevada. ........ k.tIJIiif.U if' . :.Hili ""*~,... Sf'ØIOit ,a:¡¡¡ . "'_!'I!!.'IOOU!m_ I I I I J .,¡...:."",,- Cavins Annular BOP ~ Cavins Annular BOP Schematic The combination Blowout Preventer and Sucker Rod Stripper combines safety and economy in a tool designed to peñorm the necessary function of line wiping. It can be operated from anywhere on the derrick floor utilizing pressure from bottled nitrogen, an optional hand operated hydraulic pump, or the optional BOP control system. When swabbing, a short lubricator the length of the swab between the master gate and the Blowout Preventer is all that is required. Pressure connection is for 1/4" A.P.I. pipe. The units are testèd to give full closure up to 3000 psi well pressure with no leakage. The full closure feature of the Blowout Preventer will give a temporary seal, allowing ample time to close the master gate should a well blowout occur. BALL LOCK OIL SAVER The use of the Ball Lock Oil Savers by drilling and production departments has earned this service proven tool a reputation for trouble-free operation with simplicity. The CAVINS Ball Lock Oil Savers are made of high carbon steel and precision machined for demanding dependability and safety in a wide range of service applications. Exhaustive testing in the excess of 3000 psi is further assurance against failure or leakage. Incorporated in its design, which affords a cleanly wiped wire line, is its safeguard against blowout. One important feature of the Oil Saver is its automatic ball release design. Hardened Steel Balls hold the traveling assembly securely in the body until released by the upward travel of the Rope Socket. The Rubber Packing unit with its internal fins provide the ultimate in wire characteristics with only a normal pressure, or drag, on the line. The Packing Rubber is compounded of special abrasive and oil resistant properties to give the rubber longer wear. A tough spark-proof die cast alloy is utilized in the top and bottom line guides and enhances Hydraulic Pump and Hose reduced wear in the rubber packing unit. A high quality leather hydraulic packing ring wards against leakage in the area between the body and the traveling assembly. The Hydraulic Bonnets provide an even greater degree of wiping efficiency. The wire line can be completely stripped of all oil, or water and an Oil Saver outfitted with a Hydraulic Bonnet foregoes the necessity of tools for "taking up" wear in the packing element. The one hand operation requires only a few strokes of the pump handle to give complete wiping action or turn the release valve when no wiping is Ball Lock Oil required. The Hydraulic action affords a greater rubber contact suñace as the packing rubber is compressed Saver around the line. The line is completely surrounded and sealed from blow-out leakage by the action of the Hydraulic unit. There is no danger of packing rubber or other elements falling into tlíe well. Core Program 2003 APD 2 3 4 5 6 7 8 9 -r :,1 Kill Line 10 B.a: 'Ii: Core Program 2003 APD ~ e e Well Control Diagrams Core Program 2003 Matanuska-Susitna Borough, Alaska Rig Floor 18-5/8 Inches 13 Inches Choke Line 1. Oil saver fitted with stripping rubbers to fit 3/16" slick line. Can be operated manually andlor hydraulically. 2. Cross over from drill pipe thread to 4" API LP thread. 3. Relief valve for lubricator. 4. Lubricator made of HQ drill pipe. Rated to 4600 psi. 5. TIW (stabbing valve). Rated for 3000 psi. Used for shutting in drill pipe 10 to rig up for pulling core. 6. Drill pipe sitting in foot clamps during coring operation. 7. Cavins 4" 3000 psi Annular BOP. BOP can be operated manually or hydraulically. Will be fit with rubbers to provide pressure control on the outer tube of the coring assembly. 8. 4" Full port 3000 psi valve. 9. Standard spool threaded to fit 4" line pipe connections wI two 2" ports that will be fitted wI 3000 psi full port ball valves. 10. 4" API line pipe surface casing. NOTE: ALL CONNECTIONS ARE THREADED e e , Tubular Information Core Program 2003 Matanuska-Susitna Borough, Alaska Drill Pipe (HQ) Size Pipe Weight ID Drift Collapse Burst Tensile Capacity Capacity 6" Hole 6" Hole Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (k-Ibs) (bbllft) (ftIbbl) (bbl/ft) (ftIbbl) 3.5 HMQ 4.5 3.188 3.188 3910 4600 88.46 0,00911 109.7 0.02307 43.35 u ace asmg Size Pipe Weight ID Drift Collapse Burst Tensile Capacity Capacity 6" Hole 6" Hole Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (k-Ibs) (bblslft) (ftIbbl) (bbllft) (ftIbbl) 4.5" LP X42 10.8 4.026 4.026 2650 3320 0.01574 63.51 0,0153 65.36 Sch 40 5 rf C Core Program 2003 APD e e Core Program 2003 Matanuska-SusitnaBorough, Alaska List of Exceptions For Drilling Exception #1 Regulation 20 AAC 25.030 - CASING AND CEMENTING. (f) Except for through-tubing drilling, a formation integrity test must be peñormed if BOPE is installed on a casing. The test must be peñormed to a predetermined equivalent mud weight, leak-off, or fracture pressure as specified in the application for the Permit to Drill. The test must be conducted after drilling out of the casing shoe into at least 20 feet but not more than 50 feet of new formation. The test results must demonstrate that the integrity of the casing shoe is sufficient to contain anticipated well bore pressures identified in the application for the Permit to Drill. The test procedure followed and the data from the test and any subsequent tests of the formation must be recorded as required by 20 AAC 25.070 (1). Authority 20 AAC 25.030 - CASING AND CEMENTING. (g) Upon request of the operator, the commission will, in its discretion, approve variances from the requirements of (b) - (f) of this section to allow for special or unusual conditions if the design requirements of (a) of this section are satisfied. Justification No intermediate casing will be set and surface casing will be set relatively close to surface; therefore, a formation integrity test is not valid. Exception #2 Regulation 20 AAC 25.033 - PRIMARY WELL CONTROL FOR DRILLING: DRILLING FLUID PROGRAM AND DRILLING FLUID SYSTEM. c) A drilling fluid system intended to maintain the wellbore in overbalanced condition must include (1) a recording drilling fluid pit level indicator with both visual and audible warning devices located in the immediate area of the driller's station; (2) a drilling fluid measuring system or trip tank for accurately determining drilling fluid volumes required to fill the well bore on trips; (3) a drilling fluid flow sensor with a readout convenient to the driller's station to enable the operator to determine whether drilling fluid returns equal drilling fluid pump discharge rates; Authority 20 AAC 25.033 - PRIMARY WELL CONTROL FOR DRILLING: DRILLING FLUID PROGRAM AND DRILLING FLUID SYSTEM. 0) Upon request by the operator, the commission will, in its discretion, approve a waiver of the requirements of (c) - (g) of this section if the alternative drilling fluid program and drilling fluid system meet the design criteria of (b) of this section and the corresponding equipment and procedures are at least equally effective in preventing the loss of primary well control. Justification The steel mud tank will be placed next to the drillers console in plain sight. There will be constant circulation of drilling fluids taking returns into the cellar. The mud system will have adequate volumes for maintaining the fluid level in the hole while tripping. For this process a couple of bit trips are anticipated per hole. Lost circulation is not anticipated as indicated by the previous drilling in the area. Other wells drilled in the area were drilled using air; during that drilling operation, gas influx was not an issue. There is no indication from past drilling that hydrogen sulfide gas will be encountered. Exception #3 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (c) (1) (A) of at least 16 inches, unless a smaller diameter is approved by the commission to account for smaller hole size, geological conditions, rig layout, or suñace facility constraints. (8) the actuating mechanism for the vent line valve must be integrated with the actuating mechanism for the annular pack-off device in a fail-safe manner so that the vent line valve automatically opens before full closure of the annular pack-off; (C) the vent line must extend to a point at least 75 feet Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. Core Program 2003 APD Core Program 2003 APD Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Exception #5 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (4) (A) a hydraulic actuating system with (B) locking devices on the ram-type preventers; (0) in rotary drilling rig operations, one complete set of operable remote BOPE controls on or near the driller's station, in addition to controls on the accumulator system (F) a kill line and a choke line each connected to a flanged or hubbed outlet on a drilling spool, the BOP body, or the tree, with two full-opening valves on each outlet, conforming to the following specifications: ii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (H) a choke manifold equipped with (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's station if the operation requires a BOP stack equal to or greater than API 5K; Justification Being a mineral exploration rig, this equipment is not set up to easily accommodate blowout prevention equipment. The size of the rig and the size of the surface casing indicate that a small bore BOP is required. A Cavins 3000 psi annular BOP is requested to satisfy this portion of the secondary well control requirements. There will be no pipe rams and the blind rams will consist of a full port valve placed below the annular preventer. The annular can be closed either manually using a hand pump or by using rig hydraulics. Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary Exception #4 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (1) (A) for an operation requiring a BOP stack equal to or less than API5K, BOPE must have at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blindlshear rams in place of blind rams; and (iii) one annular type Justification The largest hole size being cored is only 3.85 inches. A 16 inch diverter vent line is not necessary. Due to the size of the location, manual valves and adjustable chokes would be sufficient to provide pressure control. The DNR states that the locations should be placed such that minimal surface damage is caused; therefore, the proposed location sizes are 45' x 65'. The location size is smaller than the required length of the vent line. (h) Upon req! of the operator, the commission will, in its dis.on, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification The proposed BOP does not have rams. This rig is not configured to have an additional set of BOP controls near the driller's console, this rig does not use BOPE on a regular basis when conducting mineral exploration. This rig is not equipped to run hydraulically operated chokes; therefore, manual adjustable chokes are requested. Due to anticipated low pressure, threaded connections are requested for the entire operation. e e Exception #6 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (10) (F) be assembled without hammer unions or internally clamped swivel joints, except that hammer unions and internally clamped swivel joints may be used on the kill line upstream of the valves that are flanged to the wellhead or tree. (e) (9) connections directly to the BOPE, other than connections described in (8) of this subsection, must be flanged or hubbed, except that suitably pressurerated quick connects may be used if a positive seal manual valve, hydraulic valve, or BOPE blind ram and an annular type preventer or sealing ram are flanged to the wellhead or tree below the quick connection; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification The proposed BOP does not have rams. Request that all connections be threaded and hammer unions be approved. Anticipated surface pressure will be well within the pressures ratings of all BOPE. This well head is not intended to be a permanent fixture for production. Exception #7 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (6) (F) be assembled without hammer unions or internally clamped swivel joints, unless the commission determines that those joints do not compromise maintenance of well control; (e) (8) connections attached directly to the wellhead, tree, or BOPE must be flanged or hubbed; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification Request that all connections be threaded and hammer unions be approved. Hammer unions to be used are rated for 5,000 psi. Anticipated surface pressure will be well within the pressures ratings of all BOPE. This well head is not intended to be a permanent fixture; and intended annular BOP is threaded. Exception #8 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (9) (A) an inside BOP and a full-opening drilling assembly safety valve in the open position on the drill rig floor to fit all connections that are in the drilling assembly; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and Core Program 2003 APD Core Program 2003 APD Authority 20 AAC 25.061 (c) - Well Site Surveys Upon request by the operator, the commission will, in its discretion, waive the requirements of this section if the operator can identify, by other equally effective means, the likelihood of encountering potential shallow gas or seabed hazards or if the commission already has information that substantiates the presence or absence of shallow gas or seabed hazards. Exception #11 Regulation 20 AAC 25.061 (a) - Well Site Surveys For an exploratory or stratigraphic test well, near surface strata to a depth of 2,000 feet in the vicinity of the well must be evaluated seismically by common depth point refraction or reflection profile analysis, or by another method approved by the commission, to identify anomalous velocity variations indicative of potential shallow gas sources. Analysis results must be included with the application for the Permit to Drill (Form 10-401). Justification These wells are intended for stratigraphic testing only; therefore, no gas production or sales will these wells. The above listed requirements will be met. result from any of Authority 20 AAC 25.055 - DRILLING UNITS AND WELL SPACING. (d) The commission will review an application for an exception to the provisions of this section in accordance with 20 AAC 25.540. The applicant for an exception shall send notice of the application by certified mail to the owners, landowners, and operators described in (1) of this subsection and shall furnish the commission with a copy of the notice, the date of mailing, and the addresses to which the notice was sent. The application must include (1) The names of all owners, landowners, and operators of all properties within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells; and (3) An affidavit by a person acquainted with the facts, verifying that all facts are true and that the plat correctly portrays pertinent and required data. Exception #10 Regulation 20 AAC 25.055 - DRILLING UNITS AND WELL SPACING. (a)(2) for a well drilling for gas, a well bore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line Justification Request that inclination surveys every 500 feet as stipulated in 20 AAC 25.050 (a) (2) be adequate for this operation. There will be no production from these wells; therefore, spacing requirements and correlative rights should not be an issue. Authority 20 AAC 25.050 WELLBORE SURVEYS. (h) Upon application, the commission will, in its discretion, waive all or part of the directional survey requirements of this section or approve alternate means for determining the location of a wellbore if the variance at least equally ensures accurate surveying of the wellbore to prevent well intersection, to comply with spacing requirements, and to ensure protection of correlative rights. Exception #9 Regulation 20 AAC 25.050 WELLBORE SURVEYS. (a)(3) surveyed by a complete continuous directional survey if a portion of the well path is less than 500 feet from a property line where the ownership by owner or landowner is not identical on both sides of the line, or if a portion of the well path is less than 200 feet from any other vertical or deviated well; the survey must be taken at intervals not more than 100 feet apart, beginning within 100 feet of the surface. Justification The use of a continuous core system prevents the use of internal check valves. employed when the core is to be retrieved A lubricator system will be (2) . the diverter system requirements in (c) of this.tion if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification Several wells have been drilled in the area through the intended formations without incident. Drilling history in the area indicates that over pressured shallow gas is not going to be a problem; therefore, seismic data collection and interpretation would be an unnecessary expense. e e Core Program 2003 APD ; . e ~u&u~ @~ &~~~ . DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS FRANK H. MURKOWSKI, GOVERNOR 550 WEST 7TH AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3650 PHONE: (907) 269-8800 FAX: (907) 269-8938 December 16, 2003 Evergreen Resources Alaska Corp. Attn. Scott Zimmerman PO Box 871845 Wasilla, AK 99687 Re: Plan of Operation Mat-Su Core Holes 2003 LO/CI 03-17 Activitv Kashwitna Lake # 1 Willow Fishhook # 1 Access Road Material Site Sheep Creek # 1 Material Site Subsurface ADL 389316 ADL 389238 ADL 389238 ADL 389238 ADL 389302 ADL 389302 Surface DNR DNR ADL 25334 to Burrow ADL 25125 to DOT DNR ADL 43689 to DOT Dear Mr. Zimmerman: Evergreen Resources Alaska Corp. (Evergreen) applied for a Plan of Operations approval to drill three core holes on shallow gas leases in the Mat -Su Valley. The three core holes are part of a larger plan to drill mineral core holes at seven possible locations to gather information on coal seams. The holes are being drilled for geological information only and do not involve dewatering the coal seams, or gas production. Core holes are drilled from small pads over a two-week period. The core is removed, the hole is plugged, and the site abandoned. The program will last approximately 8 weeks beginning in December 2003. Initial plans call for drilling 5 core holes this winter. A DNR plan of operations is required for activities at the following three sites. Kashwitna Lake #1 T20N,R4W Sec. 7: NWl/4 Willow Fishhook #1 Tl9N,R4W Sec. 3: SW1/4NEl/4 Sheep Creek #1 T22N,R4W Sec. 20: Nl/2Nl/2 These sites are on state owned surface and subsurface. Site preparation may require a few days at each drill site to clear the access route and construct the pads. The drill pads will be approximately 45 ft. x 60 ft. Drilling will be conducted 24 hours per day for about two weeks at each site utilizing a compact truck-mounted unit. Drilling fluids will be plain water and additives such as soda ash, cellulose fiber, bentonite, and barite. The proposed additives are widely used for water well drilling and mineral ( e e LOICI 03-17 Mat-Su Core Holes 2003 coring in Alaska. Approximately 100 barrels of water per core hole will be utilized from existing permitted off-site sources. Each core hole will result in approximately 7 cubic yards of cuttings. Cuttings from coring will be permanently disposed of in the core hole or buried in the cellar when the core hole is abandoned. Cuttings from unconsolidated materials such as surface gravels may be disposed of to the surface of the pad in a manner similar to the disposal of cuttings from a water well. Muds and drilling fluids will remain in the portable, above ground tanks and will be removed from the site. Drilling fluids will be re-injected into an approved Class II disposal well. The core holes will be abandoned with cement plugs in accordance with AOGCC regulations immediately after operations are completed. All man-made materials will be removed and the sites left in a clean and graded condition. Public Outreach Public Notice was published in the Frontiersman and the Anchorage Daily News on November 7,2003. Landowners of record with the Mat-Su Borough within Y2 mile of each site were sent direct mail notifying them of the proposed activity. Surface interest holders were also notified. Information was included in a direct mail out to individuals who had expressed an interest in shallow gas leasing at a previous public meeting. The full application, including maps and other exhibits, was available on DNR's website. Public Comment Summary Public comments have been overwhelmingly against approving the plan of operations for the core holes. The primary concern is not with drilling the core holes themselves. The concern is with the existence of the leases and uncertainty over impacts to drinking water aquifers, surface property rights, lifestyles, existing land use, and the quality of life that might result if the leases are developed for coal bed methane (CBM). A large majority of the public comments request a moratorium on all shallow gas permitting and activity until a buyback ofthe leases can be explored. Also, the public cqmments requested comprehensive methane seep, aquifer recharge, social, and environmental studies before any core holes are approved. Public and agency comments also discussed the applicant's stated request for an exception to lease mitigation measures concerning solid waste. DNR Jurisdiction Many of the comments addressed all the core locations. Of the seven core locations, three are on shallow natural gas leases managed by DNR, three are on Mental Health Trust subsurface, and one is on private subsurface. DNR's management authority over the proposed activities is limited to surface and sub-surface state lands. A number of approval conditions have been developed in response to the public and agency concerns and will be applied to the three core holes under DNRjurisdiction. Lease Buyback Whether these shallow gas leases should be bought back by the state is a question that is generating a great deal of public attention. The Governor recently clarified his position on this matter by stating that buying back the leases is a last resort. Ultimately, the question of whether to buy back these leases is a political one that would require a legislative grant of authority to DNR to negotiate and execute any such buy back. Without any authority to consider buying back these leases, it is inappropriate for DNR to deny this application based on the possibility that these leases may be considered for buy back. These leases are valid. In approving a Plan of Operations the commissioner can require amendments he determines necessary to protect the state's interest, but cannot require an amendment that deprives Page 2 e e LOIC! 03-17 Mat-Su Core Holes 2003 the lessee of reasonable use of the leasehold interest (11 AAC 83.158(e)). These core holes, subject to the conditions contained in this decision, are a reasonable use of the leasehold interest. Exploration v. Development Core hole drilling does not present the same issues and concerns as CBM development. Core holes are drilled from small pads over a two-week period. The core is removed, the hole is plugged, and the site abandoned. The coal seams are not fractured or dewatered and there is no residual activity required at the site. If laboratory tests reveal gas content and geological conditions that justify further testing, a pilot project could be proposed in the future at or near the site. A future pilot project will require a new public notice, review, and plan of operations approval. Alternatively, the information acquired mightexcIude the area from further consideration by the company. Most of the concerns center on development issues being considered in the Mat-Su CBM project. As things progress over the next several months, the issues associated with CBM development will be thoroughly examined. Copies of the comments received during this review have been provided to the CBM project team for consideration in their process. Environmental Studies Perfoming comprehensive methane seep, aquifer recharge, social, and environmental studies at this time is premature. The potential effects of exploration activities such as those proposed here are too small to justify the types of studies requested. If exploration is successful, the impacts of field development will be examined and the suggested infomation needs can be addressed prior to making a . decision on whether to approve development. If exploration is unsuccessful (as a majority of oil and gas exploration projects turn out to be), any studies concerning the impacts of development become moot. Requiring such comprehensive studies now would require expenditures of time and resources to generate infomation for a decision that may never need to be made. There may be a time when conducting such studies is appropriate, however that time has not yet come. Confidentiality The state (DNR and AOGCC) will obtain confidential data trom the core holes that will offer insights into the character and extent of the methane resource and an opportunity to review other geological and hydrological infomation at these locations. This infomation will allow wiser management of the surface and subsurface resources by DNR and AOGCC for the benefit of all the citizens of the state. It has been suggested that the lessee or the state share information from the core holes with the public. AS 38.05.035(a)(9)(C) provides that upon the request of the person supplying the information to DNR, all geological, geophysical, and engineering data supplied must be kept confidential. The lessee is free to share the data ifthey so choose. Information acquired, sometimes at great expense, is proprietary and provides a business advantage over others who are not as well infomed. Until a company's land position is assembled or prospect is explored it is common to not release much infomation. Well data and infomation collected by AOGCC is routinely held confidential for two years and that data will then be available for public consumption if it does not qualify for extended confidentiality. Page 3 e e LO/CI 03-17 Mat-Su Core Holes 2003 Disposal of Drilling Wastes Evergreen proposes to discharge cuttings and well bore solids to the pad surface as explained on page 11 and 12 of the plan of operations. Evergreen requests an exemption from the lease mitigation measures concerning solid waste disposal. However, DNR finds that the exemption request is based on an erroneous interpretation of the lease mitigation measures, and that Evergreen's plan of operations meets the requirements of the mitigation measures as proposed. Shallow natural gas mitigation measure 26 and 27 discuss these discharges: 26. New solid waste disposal sites, other than for drilling waste, will not be approved or located on state property during the exploration phase of leasehold activities. Disposal sites may be Q[Qvided for drilling waste if the facility complies with 18 AAC 60. 27. Drilling mud and cuttings cannot be discharged into lakes, streams, rivers, or important wetlands. On pad temporary cuttings storage will be allowed. Injection of non-hazardous oilfield wastes is regulated by AOGCC through its Underground Injection Control (UIC) Program for oil and gas wells. Mitigation measure 26 allows onsite drilling waste disposal ifit complies with the DEC Solid Waste Management Regulations (18 AAC 60). These regulations are promulgated and administered by DEC to implement state statutes. DNR consulted ADEC regarding this issue, and ADEC concluded that Evergreen's proposed activity should be regulated as mineral drilling which is exempt rrom ADEC . solid waste pennitting requirements by statutory exemption (AS 46.03.100(f)(1)). From a physical operations and impact perspective, this activity is no different than mineral coring activity. Since ADEC has concluded that the activity complies with 18 AAC 60, the activity meets mitigation measure 26. Mitigation measure 27 allows temporary cuttings storage on the pad. There are instances where cuttings are temporarily stored on the pad pending final disposition in compliance with 18 AAC 60, and by extension mitigation measure 26. Mitigation measure 27 does not preclude permanent disposal on pad when such disposal is in compliance with 18 AAC 60. The Office of Habitat Management and Pennitting (OHMP) requested containment and testing of the well bore solids and cuttings prior to disposal on site. OHMP reasons that Evergreen has not provided any evidence to support their claim that disposal on the pad would not hann fish or wildlife. The proposed measure does not list the substances to be tested or justify thresholds that might be appropriate. ADEC is the state agency with expertise in the proper disposal of solid waste. ADEC has detennined that solid waste associated with mineral core hole drilling in Alaska does not pose a significant risk to humans, fish, or wildlife. Imposing a testing requirement on these core holes is not consistent with the ADEC requirements for the same activity elsewhere in Alaska. Drilling wastes remain subject to the commissioner's ability to amend the plan of operation as necessary to protect the state's interest. To assure that state lands are left in a condition that is compatible with present and future uses, DNR is requiring additional mitigation as set out later in Attachment (1) to this approval. Page 4 e e LOICI 03-17 Mat-Su Core Holes 2003 Plan of Operation Approval The Plan of Operation has been reviewed and found in compliance with the mitigation measures and advisories contained in the shallow gas lease. The Plan of Operation is approved for the Kashwitna Lake #1, Willow Fishhook #1, and the Sheep Creek #1 subject to the approval conditions found in Attachment (1) Operation Conditions; Attachment (2) DOT Requirements; Attachment (3) Well Data Submittal Requirements; and the following: 1. Where the state does not own the subsurface, surface entry is not an exercise of the rights granted in the state lease and such entry is governed by the operator's subsurface and surface agreements with the respective owners of those estates. 2. Lessee will notify this office at 269-8776 when drilling commences at each well s,ite. 3. A Status Report for the activities conducted under this approval must be filed with this office on May 1 and November 1 each year, from the date this approval is issued and until a Completion Report is filed with the Division. Failure to file in a timely manner may result in revocation of this approval. The report shall contain a statement describing clean-up activities conducted, the method of debris disposal, and a narrative description of known incidents of surface damage. 4. The applicant shall defend, indemnify and hold the State of Alaska harmless from and against any and all claims, damages, suits, losses, liabilities and expenses for injury to or death of persons and damage to or loss of property arising out of or in connection with the entry on and use of State lands authorized under this approval by the applicant, its contractors, subcontractors and their employees. 5. The applicant shall inform and insure compliance with any and all conditions of this approval by its employees, agents and contractors, including subcontractors at any level. 6. The Commissioner of the Department of Natural Resources may require that an authorized representative be on-site during any operations conducted under this approval. 7. Rehabilitation shall be completed to the satisfaction of the Commissioner. 8. The Alaska Historic Preservation Act (AS 41.35.200) prohibits the appropriation, excavation, removal, injury, or destruction of any state-owned historic, prehistoric (paleontological) or archaeological site without a permit from the commissioner. Should any sites be discovered during the course of field operations, activities that may damage the site will cease and the Office of History and Archaeology in the Division of Parks and Outdoor Recreation «907) 762-2622). 9. This approval does not authorize activity on Mental Health Trust lands, school land, or lands owned by the University of Alaska. Legal Basis for Decision and Appeal This Plan of Operation Approval is approval is issued in accordance with Alaska Statute 38.05, 46.40.205, and Alaska Administrative Code 11 AAC 83.158 or 11 AAC 83.343. A person affected by this decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received by January 6, 2004 and may be mailed or delivered to Thomas E. Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals@dnr.state.ak.us. This decision takes effect Page 5 e e LOICI 03- I 7 Mat-Su Core Holes 2003 immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31 st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from this office or any regional information office of the Department of Natural Resources. This approval does not constitute certification of any property right or land status claimed by the applicant nor does it relieve the applicant of responsibility to obtain approvals or permits from other persons or governmental agencies that may also be required. All stipulations contained in the original lease and subsequent approvals remain in effect. If activities have not commenced, this approval expires at midnight, December 16,2006. Failure to comply with the terms and conditions outlined in the lease, the attached stipulations, and this authorization may result in revocation of this plan of operations approval. If you have any questions please contact Matt Rader at the Division of Oil and Gas in Anchorage, at 269-8776, fax 269-8943, or e-mail mwr@dnr.state.ak.us. Sincerely, ISI Matt Rader Natural Resources Specialist Attachments: (1) Operation Conditions (2) DOT Requirements (3) Well Data Submittal Requirement Page 6 Nad 27 Coords for Core Wells e . Subject:Nád 27,Co9rµs fore;,oreWells ,," ~ro:nÜ.sþ-ane Gagliårdl'f::Sharì~G@EvergreenGas.coI'Ì'l> Dat¢:"Mon, 15 'Dee"200S, 15: 12:4,6..0900 "'1þ' To: BÖb' Fleckensteîn <Bbb _ f1e:6~eìl~n@~dniittstate'~.~>.,;}fI~;::' Bob, Here are the coords (in NAD 27) for the core wells. Little Su - N = 2813373.15 E = 633118.22 Houston Pit - N = 2791671.87 E = 526782.80 Willow Fishhook - N = 2838106.12 E = 504445.60 Kashwitna Lake - N = 2866054.57 E = 487747.09 Sheep Creek - N = 2918957.46 E = 489689.87 I think that most internet converters can convert Lat Long coords to NAD 27 without a problem. I have found several free programs that can do this. At this point, the standard has become NAD 83 due to the increasing number of handheld GPS tools. Thanks, Shane 1 of 1 12/1612003 8:48 AM Alaska Department of Natural Resources Recorder's Offi... http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileT... e . 10f4 "'. \V;~~C<):";·ii.': to U"'~e Alaska Department of Natural Resources C'.::):~';/ni.!~ ,," ;;'.',,:~. r.;~o~ i't"win . "." ".. ,,,,,,,.,,,,."',,"'."'..,_.. ...,.""""."..".".""."',,,,,..... .,... .... ¡ :..:.." '5.........~. :.' :',' n i, I I'll I.Ì' II 1 ").~! t 111.::.15' '.' !; I 5.:.:..I....!·.I..¡..i.!.._~...·.!).n..U::.!~_!!!.!:.':I.!. ..., Land Administration System r l____ Case Abstract Information File Type: !ÃiJL-- File ~lImber: ¡-389316- See Township, Range, Section and Acreage? (i Yes Î No Case Si~m.!.!!;~r\' I ('1!i<.!..Dchli1 I Land Ahstract Hie: AI1L 389316 EVERGREEN RESOURCES, INC. 1401 17TII STREET, SUITE 1200 DENVER CO 80202 ('ase 7}pe: 789 O&G SIIALLOW NA T.GAS LEASE Customer: 000038534 ..__~~w Searc~.J As of 12/15/2003 DNR Unit: 780 OIL AND GAS File I,oea/ion: DOG DIY OIL AND GAS Case Status: 35 ISS/APPRV!ACTY AUTlI Status Date: 10/06/2003 Total Acres: 3969.100 Date Initiated: 02/29/2000 O.f/ice (dPrimw:v Responsibility: DOG DIY OIL AND GAS Last 1ì"al1saetiol1 Date: 12/05/2003 Case .S'uhZ~pe: SC soun ICENTRAL REGION I.ast transaction: CHNGSUB CHANGE CASE SUBTYPE Meridian: S 7bwnship: 020N Range: 004W Section: 06 Afer¡dian: S Tmvnship: 020N Range: 004 W Section: 05 /I/feridiall: S Township: 020N Rallge: 004 \V Sect iOIl: 04 J4eridian: S Township: 020ì\ Range: 004 \V Section: 07 /vleridian: S To Hl/lS hip: 020N Range: 004W Sectioll: 08 J4eridian: S Township: 020N Range: 004 W Seclion: 09 Meridian: S Fownship: 020N Range: 004 W Section: 18 ll/[eridian: S Township: 020N Range: 004W Section: 17 Case Actions . , 'r. 02-29-2000 APPT.ICATION RECEIVED Total Acres: 554 total Acres: 643 Towl Acres: 643 total Acres: 36] Total Acres: 560 Total Acres: 480 Total Acres: 368 Total Acres: 360 .. . ..' , 12/15/20033:00 PM Alaska Department of Natural Resources Recorder's Offi... http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileT... e . STATUS 11 II APPLICATION RECD SNG APPLICATlO:V FIILD BY EVERGREEA" RESOURCI:!.-5ì, INC.:. FOR T20N R4IYSMSEC'S4-9& 16-18. 06-20-2000 PUBLICATION DIRECTED PUBLlC,/nON OF PUJLlC ¡\,OTICE ORDERED FOR 6,·20/2000 IN THE A.YCIIORAGE DAlLY ¡VEJ-f~S', KENAI PE\'INSULA CLARiON AND FRO.\TJERS/vIAN. 06-20-2000 COMMENTS PUBLIC NOnC/:" ADDED TO STA TE'S ON-LINE PUBLIC NOnCE IVEBSITE AND SENT TO P()S1~"'fASTERS J,'VAREA OF APPLlC4TIO,V FOR PUBUC POST/!vG. 06-30-2000 PROOF OF PUBLICA nON RECEIVED PROOF OF PUBLICATION CERTIFIED BY ANCHORAGE DAILY N¡;;WS & FRON71ERSMAN ON 6/23/2000 AND PENINSULA CLARiON ON 6130/2000. 01-16-2003 LAND WITHIN SECllON (8) CHANGED NEW TOTAL AC 3969.100000 OLD TOTAL AC 5760 CORR¡.;cnON AFTER TITLE SEARCH. 01-16-2003 DELETE LAND SECTIONS FROM CASE TTL SECTIONS DELETED I TOTAL ACRES DELETED 640 03-24-2003 COMMENTS SllALLOW NATURAL GAS I.HASH APPUCA710N SUSPENDED PENDING API'DIL 09-17-2003 AWARD/NON-OBJECTION/INTERIM AUTHORIZATION R&B STATUS 21 21 A WRD/NON-OBJ/I~TERI\-1 10-06-2003 NOTIFICATION LESSEE DESIGNATED NEW RI:I.. (20) 20 NOTIFICATION LESSEE OLD REI. CODE 21 DISPOSAL NAME :--JOTIFICATION CII) NUMBER 38534 EVERGREEN RESOURCES, OLD CII)"# 38534 EVERGREEN RESOURCES, 10-06-2003 INITIAL OWNER SEGMENT CODE I CID NUMBER 000038534 EVERGREEN RESOURCES, \VORKING INTEREST % 100 ROYALTY INTEREST % 93.750000 20f4 12/15/20033:00 PM Alaska Department of Natural Resources Recorder's Offi... http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileT... e . 10-06-2003 INlllAL OWNER SI::GMI~NT CODE I CID NUMBER 000005467 DNR DOG ROY ALTY INTEREST % 6.250000 } 0-06-2003 ISSUE/APPROVE/ACTIVE AUnlORIZATION R&B EFFECTIVE DATE 11-01-2003 EXPIRATN DATE 10-31-2006 STATUS 35 35 ISS/APPRV/AC"TV AUTI-I 10-07-2003 STATUS PLAT UPDATE REQUESTED ATTACHMENTS SENT (Y,N): N NO ADD TO STATUS PLAT ·10-09-2003 STATUS PLAT UPDATED REQUESTED TRANSACTION: SPU STATUS PLAT UPDA TED ACTION TAKEN: C COMPLETED ] 2-05-2003 CHANGE CASE SUBTYPE CASE SUBTYPE SC SOUTI. [CENTRAL REGION X Lcgul Description 0/-/6-2003 *** FINAL I.EGAI. DESCRIPTIO,V *** T. 20:\'., R. .:/ W, Sm"~1RD MERIDIAN. AL1SKA. S/-.;CUO,V 4, SURV/~'YD)' FRACUO,vAI., ALL. 642.80 ACRI:-S: SEC710;V 5.. S{jRV'~"Yh'f), FRACTIONAL .11.1., 6-13.28 AC.'RES; SlX.TIO,\, 6, SCRV/:"YHD, FRACTIONAl., ilL!. EXCLUDING GLO LOT5 Ai''!) Us. SCRVEY 9031 uns 13. I.J AND 15, 554.19 ACRES; .'-ŒC'TION 7. SURVEYED, FRAC'7JONAl. AU. I~X('I.LiJ)j,VG G/.O LOTS 2, 6, 10 A.VD 12, A:\'D c:s. SCRVEY9031 LOTS J() AX/) 12, A.VD lH/~" /JU) OF KASHWITVA LAKE, 360.61 ACRES: SEC710X 8, SL"R VEYED, X2. SE.:/, E2SW.¡, 560.00 ACIŒS; SIXT/o.V 9, SCRV/~Tn), ;\'E4, S2, .J80.00 AC'RES; S/:"C..T/UY n, SCRVEYED. .YE.:/SE.J, S2SE4. SW.J, E2NW4, 360.00 ACIŒS; SEC7Jo.v 18, SURVI:"YU), FRAC1JO:VAL, AU. /:·XCI.CDIXG NW.JiYE.J, S/!.'-I.VW.J. GU) I.O"fS 1 TIIRe 4IW..'l.LSIVE. Us. SURVEY 9031 LOIS 6. 7, A.\D 8, AND 71ft: BED OF KASIIWI"fNA I.AK/:-, 368.22 AC/ŒS; 30f4 12/15/20033:00 PM Alaska Department of Natural Resources Recorder's Offi... http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileT... e . THIS TRACT CONTAINS 3,969.10 ACRES MORE OR LESS. End of Case Abstract F:Sack Land Admini<¡tratioI1 S'Vslem ''Ieml I Land R(>cordsfSlatusPlats I Depl. of Natural Resources Home Pagt> I Stat\~ of Alaska HOI1Jt' ra!!e I Copyri2:ht I PriV:lCl I Disclaimer Last updated on 12/15/2003. Report technical problems with this page to the ~Y~.Qmaster. Tbis site works best with 4.x or newer version of Internet Explorer and Netscape. This site also requires that aU COOKI ES must be accepted. 40f4 12/15/20033:00 PM 12/17/2003 09:05 9073337889 e W 0 VALLEE PAGE 05 . T20N,R4W, SEWARD MERIDIAN, ALASKA KASHWITNA LAKE # 1 From U.S.G.S. TopographiC Map ANCHORAGE (0·8) & TYONEK (0-1), ALASKA Dee 17 03 02: 57p DH e =V=I~GI~==I'I RESOURCES(ALASKAJCOR~ A Subsid18'Y 01 e..rgroen Resources, I11c. 907.357.8340 . p.2 December 12, 2003 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Additional Information for Evergreen Resources Alaska's Core Program 2003 Resulting from Conversation with Commissioner Seamount Dear Mr. Crandall: As a result of conversations with Commissioner Seamount, Evergreen will monitor water produced during the surface hole drilling process for salinity. Evergreen professionals will be on location with field measuring equipment to determine the depth at which a significant change in water salinity occurs. The change in water salinity as measured by Evergreen professionals will dictate the surface casing set depth for each of the wells in the core drilling program. The use of this method will ensure that the portion of the surface hole used for drinking water is protected. In the event that a deviation in water conductivity is not noticed, the Alaska Oil and gas Conservation Commission will be notified before casing is set. If you have any questions, please feel free to contact me at 907-355-8569 or sh aneq@everqreenqas.com. £i'<Iß2- Shane Gagliardi Petroleum Engineer 1075 Check Street. Suire 202 . Wasilla AK 99654 p.o, 8cx 871845 . Wasil/a. AK 99687 . TEL 907.357.813iJ . FAX 907.357.8340 =\I=I~GI~==I'le RESOURCES(ALASKA)COR~ A Subsidiary ·01 Evergreen Resources, Inc. . December 5, 2003 Ms. Sara Palin, Chair Alaska Oil and Gas Conservation Commission 333 West Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Core Program 2003 Target: Tertiary Tyonek Proposed TD: 3000 Feet Proposed Spud Date: 10-December-2003 RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commìssiol1 Anchorage Dear Ms. Palin, Evergreen Resources Alaska Corporation hereby applies for a Permit to Drill for the subject core wells located approximately 30 miles north of Anchorage. The wells are planned as a shallow, straight holes drilled to evaluate the producibility of the Tyonek Coals. A core drilling company currently operating in the Fort Knox gold mine will be used to provide a continuous wireline coring operation. The rig to be used is a CS-4000 that is typical for mineral exploration. A six inch hole will be drilled through the glacial gravel section and a string of 4.5 inch line pipe will be cemented in place. Once the cement has hardened and the appropriate test has been conducted for casing integrity, an HQ hole (3.875" diameter) will be drilled to TD. A logging suite consisting of gamma ray, array induction, compensated neutron density, caliper and sonic porosity tools will be run. After all cores have been retrieved and logs run, the hole will be permanently abandoned. Attached is information required by 20 AAC 25.005 (a) and (c) for your review. Due to the differences in equipment and methods used for mineral core drilling, Evergreen requires several variances from current AOGCC regulations. The designated contact for reporting responsibilities to the Commission is Shane Gagliardi, Alaska Projects Engineer, office: 907-357-8130 or cell: 907-355-8569. Sincerely, Evergreen Resources (Alaska) Corporation ß~ Shane Gagliardi Alaska Projects Engineer enclosures ! ~,! 1\ I Core Pr gram 2003.APD 1075 Check Street, Suite 202 . Wasilla AK 99654 ..,__,,,_ ."",,,,,,,,.. .,.,.., "^"F,.i~..,.,..^^ _ "'IiV",,,,..,",....,,,,,,,,, · e Conditions of Approval Evergreen Resources (Alaska) Corp. Kashwitna Lake #1 (PTD 203-209) 1. Per 20 MC 25.030 (g), the formation integrity test requirement is waived. 2. Per 20 MC 25.0330), the drilling fluid system requirements are waived. 3. Per 20 MC 25.035 (h) (1) and (2), the BOPE and diverter requirements are waived. 4. Per 20 MC 25.050 (h), alternate well bore directional survey intervals are approved. 5. Per 20 MC 25.061 (c), the near surface survey requirement is waived. 6. Test BOPE to 1500 psi. 7. Abandonment plug cement volumes may be adjusted dependent upon actual subsurface conditions. <,"<.' "', , ,)",.,--/, ,:,c,:,,-,-::: ','..':':,."-" . . One Hundred Dollars and Zero ontrolled Disburse[T1ent AGCOUn~' ,-':, . .. .. .ernia Natio Evergreen Resburces (Alaska) 1401 17th Street Suite 1200 Denver CO 80202 303-298-8100 Check Date 0077000725 12/08/2003 \Ìöid After 90 Days ~G?t?~ ^PLEASE DETACH AT PERFORATION ABOVE^ ^PLEASE DETACH AT PERFORATION ABOVE^ Evergreen Resources (Alaska) Corp 1401 17th Street Suite )200 Denver CO 80202 303-298-8100 112403SG 11/24/2003 12 mono permit fee Kashwitna Lake 1 100.00 0.00 100.00 I 009195 I ~ Vendor Check Date: 12/08/2003 Check Amount ~ I 100.00 I . . TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well ~ Permit No, API No. . (If API number Production sbould continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) . and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing e:xception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrougb target zones. Rev: 07110/02 C\jody\templates WELL PERMIT CHECKLIST Field & Pool PTD#: 2032090 Company EVERGREEN RESOURCES (ALASKA) CORPORATION Initial ClasslType Administration 1 Pß(mitfee ¡¡¡ttaçhe~ Ye$ 2 Le¡¡¡sßnumberappropri¡;¡le _ Ye$ 3 _U_nique weltn_amß.aod oumb.er . . .Yß$ . . . 4 WellJQc¡;¡tßd in a define~pool_ No 5 WeJUQc¡;¡tßd prpper _distance_ from driJling unitb9und_a(y. Yß$ 6 WelllQc¡;¡tßd pr.oper .distaoce. from otber wells. Yß$ 7 .S.utfiçientaçre¡¡¡geav¡¡¡il¡;¡ble indrilliog unjt Yß$ 8 Jtdßviated, js. weJlbQre platincJudedNA 9 .Oper.ator onl)' affeçted party _ Yß$ 10 .Oper.ator bas.appropriateJ~ond inJorçe Yß$ .. . . . . . . . 11 pß(mil çao be iS$ued wjtbQut cOMerva_tion order _ Ye$ Appr Date 12 pß(mil cao be iS$ued witbQut ¡¡¡ctminist(atÏ\,e.apprpvaJ . .Yß$ RPC 12/17/2003 13 Can permit be approved before 15-day wait Yes 14 WeIUQc¡;¡tßd within ¡¡¡rea ¡¡¡nd_strat¡;¡ _authorized by.lojectioo Ordß( # (pullO# h commßots) (For _NA 15 AJlwells.withinJ14J'uile.area.of(eviewid.eotified(Fp(servjc.eJN.etlonly).. .. ..NA. . . .. .... ..... 16 Pre-produ.cect iojector; ~uralionof pre-pro~uction Iß$s th¡¡¡n 3 months. (For.ser:vice well onJy) NA 17 ACMPFindjng 9f Con_sisleocy.h.a$ bee.nJssued_ forJbi$ proieçt NA 18 _Cooduclor st(ingprovidßd NA 19 S_ud¡¡¡cß casing protects alLknown USDWs Yßs 20 _CMT vpl adequ.ate. to çirc.u tate. o.n .cond.uctor. & surtcsg Yßs 21CMT vol adequateJo tie-in .long .striog lo.sud csg. NA 22 _CMTwill c;over.aJl kno.w.npro_duc;tive borizons_ No 23 .C.asiog desigos ¡¡¡deQua1e fp( C,T, B& permafr.o$t Yß$ 24 _Mequale.t¡¡¡nkage.or re.serye pit Ye$ 25 Jta.re-d(iIL has_a 10-403 fQr abandon.me_nt beßO ¡;¡pproved NA 26 .Mequalewetlboresepar¡;¡tio.n.proposeçl. . .. Yß$. .. . 27 Jtdjveder req.uired, dQes it meßl reguJations NA Requirement waive~, Appr Date 28 .Drilliog fluid. program $chematic_& equip Ji$tadequ¡;¡le _ Ye$ . Waler. . WGA 12/18/2003 29 BQPEs, do they meelreguJa1ion NA _ 8nnula( only_. 30 .B.OPE.pres$ ra.tiog app(op(iate;test lo(put psig in _comment$). _Ye$. Test lo 1500 psi. MSF> 1080 psi. 31 .C.hoke.manjfold çompJies w/APtRF>-53. (May 64). NA 32 WQrk will oc;c.U( withoutoperatjo_nsbutdown_ Ye$ 33 Js preseoce. Qf H2S g¡¡¡S_ prob.able _ No. 34 MecbanicaLcoodJUoo pf well$ within 80R verifiect (For.s_ervjce wßII only) . _NA Engineering Appr RPC 35 36 Date 37 12/17/2003 38 39 pß(mil c_ao be iS$ued wlo. hyd(ogen. sulfide me¡¡¡suœs . .D.ata.preseotect On pote_ntial overpres_sure _zoneJ). SßismicanalysJs_ Qf sbaJlow gas.z.ooes. .Sßabedconditioo survey (if off-sh.o(e) . CQnta_ct namelphone}orweekly progress reports [e¡cplorato(y .ooly). Geology Geologic Commissioner: /jrs Date: Engineering Commissioner: Date Public Commissioner ?f? ~~// ;v- 1<_ J fJjJ Well Name: KASHWITNA LAKE 1 STR /INFO GeoArea D D Program STR On/Off Shore On Well bore seg Annular Disposal Unit This is a strat .test, no production Qr testing_ will occur, There. are 00 correlativerigbt$ issues _a$s_oçiatßd _ with tbe driJling of tbi$ well. RPC. e . . . Set @ 200 ft. No casing below surface. Stra.tigr¡;¡phJç tesL Core rig taoks, e Ye$ NA NA NA NA . ..