The URL can be used to link to this page

Home My WebLink About202-011Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 29, 2024 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7017 2400 0000 5648 0879 Patrick Lawrence Pearl 4432 Old Redwood Hwy Santa Rosa, CA 95403 RE: Well Site Clearance – Pearl No. 1 Well (Permit to Drill 202-011) Dear Mr. Pearl: The Alaska Oil and Gas Conservation Commission (AOGCC) is the state agency that regulates oil and gas drilling in the state of Alaska. Part of our duties are to make sure that wells are drilled safely, and when there’s no more utility for the well that they are properly plugged and abandoned, and the drill site is properly restored. In February and March 2002 Union Oil Company of California (Unocal)1 drilled the Pearl No. 1 well on land which Kenai Peninsula Borough records indicate that you currently own near mile marker 132 of the Sterling Highway (Kenai Peninsula Borough Parcel ID No. 15703083). Unocal later plugged and abandoned the well in accordance with AOGCC regulations, and the plugging operations were verified by an AOGCC field inspector on April 12, 2003. Although the well is mechanically properly plugged and abandoned, AOGCC regulations also require operators to conduct site clearance work and successfully pass an AOGCC site clearance inspection. Specifically, 20 AAC 25.170(a) states: At or after the time that a well drilled onshore is abandoned and before the earlier of one year after well abandonment or the expiration of the owner's2 rights in the property, (1) the operator shall remove the wellhead equipment and casing to a depth at least three feet below original ground level and install a well abandonment marker in accordance with 20 AAC 25.120; and (2) unless the operator demonstrates to the AOGCC that the surface owner has authorized a different disposition to facilitate a genuine beneficial use, the operator shall (A) remove all materials, supplies, structures, and installations from the location; (B) remove all loose debris from the location; 1 (ƯôèťĖŽôϙŕŘĖīϙ͒͏Ϡϙ͑͏͐͘ϠϙēôŽŘĺĲϙϙIĲèϟϙÍèŗŪĖŘôîϙĲĺèÍīϙÍĲîϙťēŪŜϙæôèÍıôϙťēôϙĺŕôŘÍťĺŘϙĺċϙŘôèĺŘîϙċĺŘϙťēôϙ ôÍŘīϙbĺϟϙ͐ϙſôīīϟ ͑IĲϙťēĖŜϙĖĲŜťÍĲèôϙЊĺſĲôŘЋϙŘôċôŘŜϙťĺϙťēôϙĺŕôŘÍťĺŘϙϼĲĺèÍīϙÍĲîϙťēôĲϙēôŽŘĺĲϽϠϙĲĺťϙťĺϙťēôϙīÍĲîĺſĲôŘϟ Pearl No. 1 Well October 29, 2024 Page 2 of 2 (C) fill and grade all pits or close them in another manner approved by the AOGCC as adequate to protect public health and safety; and (D) leave the location in a clean and graded condition. Unocal (Chevron) completed the activities required under part (1) of this regulation by removing the wellhead, cutting the casing off below ground, installing a marker plate and a marker post, but Unocal never arranged for the AOGCC to conduct a site clearance inspection. The AOGCC does not know if Unocal (Chevron) complied with requirements (2)(A) through (2)(D), above, or if they otherwise left the well location in a condition acceptable to you. If the site was not cleared in compliance with 2(A)-(2)(D), the AOGCC may potentially have means at our disposal to remedy the situation. Please send a letter or an email to the AOGCC (at the letterhead address or to dave.roby@alaska.gov) advising as to whether or not Unocal (Chevron) left your property in a manner that is acceptable to you after plugging and abandoning the Pearl No. 1 well. If you have any questions, please feel free to contact Dave Roby of our staff at 907-793-1232 or the above email address. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Meredith Guhl, Geologist Assistant, AOGCC Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.28 18:13:05 -06'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.29 03:55:52 -08'00' . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Insens\Microfilm _ Marlœr.doc Permitto Drill 2020110 MD 8000 TVD REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number Log/ Data Type I Log i Log I - I~ , Log Log Log Log Log Log Log Log Log JJ.<¡g I ! Log I Log Well Cores/Samples Information: J q rEI- fì Â (¡Ôt.! DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Well Name/No. PEARL 1 Operator UNION OIL CO OF CALIFORNIA 8000 Completion Date 3/19/2002 Completion Status Mud Log No Samples No Name Log Log Run Scale Media No 2 Co! 1 Name Interval Start Stop 5 5 5 BM BM BM 3 3 3 3 5 5 5 BM BM 3 3 3 3 5 5 BM BM BM 5 5 5 BM BM 3 3 3 BM BM BM BM 3 3 5 5 5 3 Sent 1-GAS Current Status P&A \ API No. 50-133-20509-00-00 UIC N Directional Survey No 511'""'JL't- .!~~ (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH 300 8000 Open 3550 6954 Case ~O 6066 ...-cáse 3550 100 100 100 100 3550 3550 3550 3550 3690 3550 3550 Received 10/3/2002 10/3/2002 6954 6948 6948 6948 6948 6607 6607 6607 6954 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 Case 10/3/2002 4250 6954 Case 10/3/2002 Case 10/3/2002 6607 Received Sample Set Number Comments ) Comments Top of Fluid Determination 2" PJ HSD, 6 SPF Top of Fluid Determination Top of Fluid, Sample Top of Fluid, Sample Top of Fluid, Sample Top of Fluid, Sample Top of Fluid, Sample Top of Fluid, Sample Top of Fluid, Sample Top of Fluid Determination 2"PJHSD,6SPF~ Top of Fluid Determination I Top of Fluid, Sample I .J ) DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 PermittoDrill 2020110 Well Name/No. PEARL 1 Operator UNION OIL CO OF CALIFORNIA API No. 50-133-20509-00-00 MD 8000 TVD 8000 ADDITIONAL INFORMATION Well Cored? GJI N Chips Received? Y (;) y~ tL~~;~~ ¡jw~ r- M '( <Jo-'I( $ ~ ~ ? ~I)ì ---=? '7 3 v((, \- r!'-l~ U ~ \fì¿~ ~ Completion Date 3/19/2002 Completion Status 1-GAS Current Status P&A UIC N Formation Tops 0N yG) Daily History Received? Analysis Received? Comments: Nò ~>O'! - 'Ii b (I . 1"1 I I=-W\~('C!.- ..c...V ~V"":.Ii-- ¿ L-{.¡...¡(.....,I,.. 3-/J.p ~ ~ . - þ,I),I'I)" ~ ~ ~~ / f-A" Yr- /.:L ~ ~ "/ ) Compliance Reviewed By: Date: ~~~~~~ ~~ - . - jlr.Q.-J: , y~ rt.r:t .. ~ -\JJ JJ.J~.1~ IJk~ ! r H1cJ.2t tt ßtv l~1fr\I""" r Ulfió (CJ j Å ~ (Lv Ìv~"{ - F'ó L(,¡¡",J, ViA' - ~.. ) ~ ~ !....-' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519-6247 4. Location of well at surface 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM At Top Producing Interval 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM At Total Depth 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No, 17.37' RKB Private 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 2/17/02 3/03/02 4/11/03 Abandoned N/A feet MSL N/A 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 8000' MD Yes: No: X feet MD 22. Type Electric or Other Logs Run SUSPENDED: ABANDONED: x SERVICE: 7. Permit Number 202-011 8. API Number 50- 133-20509-00 9. Unit or Lease Name Pearl Lease 10. Well Number Pearl No.1 11. Field and Pool South Ninilchik Prospect 23. CASING SIZE WT. PER FT. GRADE 13-3/8" 61# K-55 9-5/8" 47# L-80 7" 26# L-80 7" 29# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 71' Surface 2140' Surface 9926' 9800' 10578' HOLE SIZE DRIVEN 12-1/4" 8-1/2" 8-1/2" CEMENTING RECORD DRIVEN 230 SX AMOUNT PULLED 0 0 0 0 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) SIZE 3-1/2" TUBING RECORD DEPTH SET (MD) 3788' PACKER SET (MD) 3706' 25. None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc,) PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS OIL RATIO TEST PERIOD => - Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 27. Date First Production Date of Test N/A Hours Tested Mud Log already submitted to AOGCC RECEIVED APR 2 9 2003 J r::,<r['I\ <;(;/"7 >.-$ f:t)- ~ CL ~ ~ ""Òf~:i\.";'. i $¡i;:! J L~~~~~./ Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 ORiGiNAL Cy 'V' CONTINU~D ON REVERSE SIDE fØ)MS Bf L Submit in duplicate AfR 302003 ~. ~ 29:- 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. RECEIVED .APR 2 9 2003 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Well Schematic and summary~ons. 32. I hereby certify th" reg~r~e rnd correct to the best of my knowledge 51 ~,;\A rrtæ t\ rot Lj f^~\. Date L\ L~CJ"1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in. Other-explain. Item 28: If no cores taken, indicate "none". --"'"' Form 1 0-407 OR\G\NAL UNOCALe ELEVATION: RKB=17.37' - Wellhead removed - Casing stubs cut 7-112' below GL - Marker post above GL. Driven 13-3/8" 95' 9-5/8" @ 1791' Cemented to Surface 1 - Cemeht from 3700' to 3000' 2 3 4 Perfs 4000'- 4008' ~ S/"',.TH NINILCHIK '" etl PEARL # 1 Final Abandonment CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surface 95' 9-5/8" 47 L-80 Butt 8.681 Surface 1,791' 7" 26 L-80 Butt Mod 6.276 Surface 4,445' 7" PES 26# L-80 Butt Mod 6.184 5103' 5106' Cmtr T' 29 L-80 Butt TKC 6.184 4,445' 8,000' Tubing 3-1/2" 9.2 L-80 Butt SC 2.992 Surface 3,788' 3/8" .25 416 SS Continuous .25 Surface 1,968' NO. I 2 3 4 ID 2.990 2.990 2,661 2.990 JEWELRY DETAIL OD Item 5.437 Chemical Injection Mandrel SAB 40-32 Baker Packer "XN" Nipple Shear Out Ball Sub wi W/L Entry Guide Depth 1968' 3706' 3,754' 3788' Perforations Date Zone Top BTM Length Comments 3/19/02 7800 7798' 7836' 36' 2", PJ, 6spf, 60 deg 3/25/02 7300 7289' 7319' 30' 2", Pl, 6spf, 60 deg 3/28/02 5700 5694' 5734' 40' 2", Pl, 6spf, 60 deg 3/29/02 4000 4008' 4043' 35' 2", Pl, 6spf, 60 deg 4/8/03 . 3696' 3700' 4' Tubing punch 4/10/03 870' 875' 5' 2.5",6 SPF, 60 deg CEMENT HISTORY Cement from Date String Size Depth Volume Comments 3810' to 5734' of Cmt 2/20/02 Surf 9-5/8" 1791' 122 Cement Circulated to Surface with BBLS 40+ BBLS Perfs 5694'- 3/07/02 Prod 7" 8000' 100 FIRST OF TWO STAGE JOB 5734' BBLS WITH DV TOOL AT 5103'. TOC STAGE 1 AT DV TOOL ~.."...~ 3/08/02 Prod 7" 8000' 70 SECOND STAGE JOB BBLS TOC EXPECTED AT 2700'. TOC ::= Perfs 3/29/02 4000 4008' 4043' 35' 2", Pl, 6spf, 60 deg 6954' 7289'- 7319' IîI PBTD = 6,945' ELM TD = 8,000' Vertical PEARL # 1 >: ) Plug at 7755', TOC = 7730' - Perfs 7799'-7835' DRAWNBY:DED REVISED: 4/23/03 ,..--" /~ Operations Summary Pearl #1 Final Abandonment Day 1 (4/5/03): Cleared water from cellar. Day 2 (4/6/03): Prepped well for abandonment. Day 3 (4/7/03): RU on 7" x 9-5/8" annulus, pressure test to 1950 PSI--unable to establish injection. RU on 3-1/.2" tbg and performed injection test. Pump cement to perfs below packer from 3,810' to 5,734'. Day 4 (4/8/03): RU e-line unit. RIH and confirm TOC w/ tag @ 3810'. Perf tbg from 3,698'-3,700'. POOH and RD. Day 5 (4/9/03): RU cement lines. Spot balanced cement plug from 3,000 - 3,700' in both the 3-1/2" tbg and 3-1/2" x 7" annulus. Day 6 (4/10/03): RIH w/ e-line to 870' and perfed tbg. (5' gun 6 SPF w/ 50 degree fase). Circulate well. RU cement lines. Spot balanced cement plug in 3-1/2" tbg, 3-1/2" x 7" and 7" x 9-5/8" casing annuluses from surface to 875'. Day 7 (4/11/03): Finished cement job including chemical injection lines and RD cementer. Day 8 (4/12/03): Remove wellhead and install abandonment marker as per AOGCC regulations. RD/MO Last revised 4/25/2003 (DE D) . . \ .~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich, ~ Commissioner .11.;10".7 Î2J1A ,?\"'7\ Jim Regg, . \ v'lq . P. I. Supervisor April 12,2003 DATE: THRU: FROM: Jeff Jones, Petroleum In.spector SUBJECT: Surface P & A Unocall Pearl #1 202-011 Exploration April 12, 2003: I traveled to the South Ninilchik Prospect to witness a surface abandonment operation on Unocal's exploration well Pearl #1. Steve Lawrence was the Unocal representative for the abandonment operation today. On my arrival the 13 3/8", 9 5/8", 7" and 3.5" casings had been cut to 7' below final grade. Cured cement was visible in all annuli to 3" below the cut. This remaining void was topped off with cement and a %" steel cap plate was seal welded to the outer casing diameter. A 13' long sealed 6" diameter marker post with the AOGCC required well information bead welded on the upper surface was solidly welded to the casing cap plate and reinforced with four steel gussets. The marker post extended 6' above final grade. This abandonment marker post installation complies with AOGCC regulation 20 AAC 25.120. The AOGCC Location Clearance Report and photos (5) are attached for reference. Summary: I witnessed the casing cut off and marker post installation on Unocal's South Ninilchik Prospect exploration well Pearl #1. Attachments: LOCLEAR Unocal Pearl #1 4-12-03 JJ (1) Photographs (4) NON-CONFIDENTIAL LOCLEAR Unocal Pearl #14-12-03 JJ.doc . . ~ Q d) S Q 0 ~ Eã ..D < ~ =+t:: ~ ~ cd 0) ~ , ----. /"--" ,---, ~, , . .. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ~ DATE: April 8, 2003 Commissioner ÎJ'ft ~41'?> SUBJECT: Plug & Abandonement THRU: Jim Regg Pearl #1 P.I. Supervisor Unocal South Ninilchik Prospect FROM: Jeff Jones Exploration Petroleum Inspector 202-011 CONFIDENTIAL Section: 24 Township: 01S Lease No.: N/A Drilling Rig: APRS wireline Operator Rep.: Steve Lawrence Range: 14W Rig Elevation: 17.37 RKB Meridian: SMAK Total Depth: 8000' CasinalTublng Data: Conductor: 133/8" O.D. Shoe@ 95' Surface: 95/8" O.D. Shoe@ 1791' Intermediate: O.D. Shoe@ Production: 7" O.D. Shoe@ 7983' Liner: O.D. Shoe@ Tubing: 3.5" O.D. Tail@ 3788' Casing Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Retainer PlugginG Data: Bottom Top of Cement of Cement Depth Verified? 7755' 3800' Wireline tag Mud Weight above plug 12.5 ppg Pressure Test Applied 1500 PSI Jype Plug CbottomLlP) Perforation Founded on Type Plug Open Hole Perforation Annulus Casing Stub Surface Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No April 8, 2003: I traveled to Unocal's South Ninilchik Prospect to witness abandonment procedures performed on exploration well Pearl #1. Steve Lawrence was the Unocal representative for the tests today. The subject 76 BBL 12.5 ppg class "G" cement plug was laid inside the 7" casing from the top of a previously installed cement plug at 6945' and allowed to cure for 12 hrs. +/-. I witnessed the successful pressure test of the 7" casing and cement plug to 1500 PSI. I then witnessed Alaska Pipe Recovery Specialists run in the hole with a tubing punch and weight bars and solidly tag the top of cement at 3800'. This plug isolates the remaining open perforations (bottom @ 5734' - top @ 4008') 'in this well according to the requirements of AOGCC regulation 20 Me 25.112. Summary: I witnessed the successful pressure test and wireline tag of a cement abandonment plug in Unocal's exploratory well Pearl #1 in the South Ninilchik Prospect. ££i Evan Harness (Unocal) Attachments: Pressure Test chart (1) Well bore Schematic (1) Distribution: orig - Well File c - Operator c - [)NRlDOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by loR.G. P-A Unocal Pearl #1 4-8-03 JJ.xls 5/5/2003 ". .. ¡ "....--.... """"""'. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment I Location Clearance I Suspended Well ( Title 20 AAC 25.170 ) FILE INFORMATION: Operator: Unocal Oil & Gas Address: 909 W. 9th AVE Anchorage, AK 99501 Surface Location (From Sec. Line): North/South 1568' FNL EastlWest 1968' FSL Section:~ Township: 01S Range: 14w Meridian: SM Well Name: Pearl #1 PTD No.: 202-011 API No. 50- 133-20509-00 Unit or Lease Name:South Ninilchik Prospect Field and Pool: Exploration Downhole P&A Date:4/8/2003 20 AAC 25.120 . ABANDONMENT MARKER: Insp. ()ate:4/12/2003 I Suñace Monument Post OD: (4" min) 6 " Length: 13 ft. Height above final grade (4' min.): 6 ft. Top of Marker Post Closed ~ Insp, Date: 4/12/2003 I Approval Date: Set on Casing (Wellhead, Csg , In Cmt) Casing stub:!.... ft. below final grade All openings closed ?yes Inspector: Jeff Jones Subsuñace Monument I Approval Date: Distance below final grade Level: Side Outlets removed or closed: Cement to surface (all strings)? Inspector: Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: I I Approval Date: 4/12/2003 Insp. Date: I Marker Plate Diameter: Thickness: - Marker Plate Attached To Conducto.!....- (Y/N) UNOCAL API # 50-133-20509-00 PTD 202-011 Pearl # 1 Insp. Date: I Pit's filled in? Inspector: Jeff Jones 20 AAC 25.170 - LOCATION CLEANUP: I Approval Date: Liners Removed or Buried? Debris Removed: Ncltes: General condition of pad/location: Ncltes: ( Rough, Smooth, Contoured, Flat, Natural) Type of area surrounding location: Debris on surrounding area: ( Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Notes: Access road present? Condition of road: ( Dirt, Gravel, Ice, Other) Condition: Type road: Notes: Cellar filled in? Height above grade: Type offill: Notes: Type work needed at this location: Inspector: RECOMMENDED FOR APPROVAL OF ABANDONMEN Yes No ( If "No" See Reason) Distribution: orig - Well file c - Oporator c - Database c - Inspector Reason: Final Inspection performed?Yes No Final Approval By: Title: DATE: Sheet by L.G. 8/5/00 LOCLEAR Unocal Pearl #1 4-12-03 JJ.xls ./\~\Ï):7 ~"J ~ ~ 5/5/2003 a4/a7l2f1ø3 fie: 57 ~ 9a7271:.. A2 ..........- UNOCAL8 AOGCC PEARL #I 1 WELLBORE SCHEMATIC ELEVATION: 222.5 Feet SIZE 13-3/8" ACTtJALRJ<JI.. 11.31 !M/8" Om. 13-318" 95' ~@ 1"1' c.u"lft SuTf'KI! "':7:::: ¡i1 ;:~'~;~ ïf;::~; f:f;':-.: Ij',j..'., ~;,;;!:':,ì 6 ;:,,;,~ ~:;~ i.~\. f;;..J 2 - !iir ~ ~ ~ ~ ~ Toe ON STAGE 1 . 5100' Perfs 5694'. 5734' Perfs 7289'- 7319' CASING AND TUBING DETAIL WT GUDE CONN 10 TOP BTM. 61 R.5S Butt 12.5U Surface 9S' 4? t...so Butt 1.681 SurlIIce 1,191' 26 wo Butt Mod 6.176 Sur&ee 4,445' 26# f.-SO Butt Mad 6.184 5103' 5106' 29 L-8O Butt TKC 6.184 4,445' 8.000' t,2 1A0 Butt SC 2..992 SIIrl'a&:e 3.788' .25 416SS Con1ÎnUOUll .25 SurJD 1.968' JEWELRY DETAIL No. .. I~ OD INM .. 1 1'-3" 2.992 " II" Tubi1lg Hanger, 3.1¡¡" 2 )%8' 2.990 ,A37 Chemièa/ InjeétiØII Mandrel 3 3106' 2.990 SAS 40.32 EJ.lter '~CT of 3,754' 2MJ "XN" Nipple $ 3788' 2.990 SlIeIr OUt Ball Sub wI W IL &my Gum 6 TBD 1" 1"'P1!S Cmtr T' "f'ubñaJ 3.111" Y8" ~ ZoM Top 3119"% 7800 7798' 3125182 7300 7289' 3I:ZMZ 5700 S694 ' 3129"'% 4000 4008' ""..... .. Date Stri.. Size 2I2Om: Surf' 9-518" 3107102 Prod 7" 31OMZ Prod 7" :J12:v02 Test Zoo Perfs HSD6 SPP 3f21i1M Test 2" Pm15 HSD 6SPF Perfi; 7799'.7835' TD. 1,000' PEARL * ) f\ì1P\C\-\, ~ PAGE fll )UTB NINILCHIK '--- Well PEARL #I t Actual Cempletion 3129103 Mobnol JtúeotiO1l r..~. - - . perforatio.. 8TM Leaa&h 7836' 36'- . 1319' 30' 5734' 40' 4043' 35' COIIIIIIIIItt . -. ;2", PI, 6spt 60 deS 2", PI, 6spf, 60 deS 2", PJ, 6spf, 60 del 2", PJ, 6spf, 60 del .., , ...,- CEMENT mSTORY Depda Vol of c~ C.. 1791' 122 Cemmt Ciiëulaticfto Surface with ' -- BBLS 40+ SBLS 8000' 100 FIRST OF TWO STAGE JOB BBLS WITHDYTOOLATSIO3', TOCSTAOE 1 ATDVTOOL 8000' 70 SECOND STAGE JOB BBLS TOC EXPBCTED AT 2700'. TOe @ 2S' = Set Posiset Plug and Dump 7729' 1 NL Baí1ed cement from 77SS' to 7729' TOe @ 27 Ptaced cement witb Coiled Tubing. 694" 88LS Tested Plug to 1750 psi. DRAWN BY: U,M, REVISED: 31Z6/03 JIM \0 FILt: P- A IJ..V\öco..\ t>eo-r\ :ti::1.. t.f-8-63 Jj .x\s ~, Schlumberger Well Pearl #1 Field Wildcat Engineer J.\.lbin Hale Country United States Time """"""..",." 08:37:26 08:47:00 08:57:00 09:07:00 09:17:00 09:27:00 09:37:00 09:47:00 09:57:00 10:07:00 10:17:00 10:27:00 10:37:00 10:44:54 hh:mm:ss "I<"""""~'" -- Pressure '----r j c::::=- c::::::=. -- .~. ;ementing Job Repol Client Unocal SIR No. 2200940402 Job Type Pressure Test Casing Job Date 04-08-2003 . Rate Density ....... L ). :=J ~ .-J c:::::~ ?- t( LJ 0.00 2000 sooo 0.00 - - 1000 --PSI fT rt- Ac. ~ '\0 ~\LC¿ , 2.0 8.0 15.0 10.0 5.0 10.0 <.0 6.0 81M LB/G CemCAT v1.0 Messages Pressure test Casing Pressure Casing to 1500 psi Bleed Off Pressure Pressure up Casing to 1500 psi Bleed Off Pressure Pressure Test CasIng Pressure Test Tubing Bleed Off Pressure Pressure Test Tubing Bleed Off Pressure Pressure Test Tubing ~ 2'.0 ~ - p\ \A 1'\ 0 (..c-\. \ -ç:>~C\V" \ ,t1-i Lf -~-O~ ,J,\ ,'>1. k 04/08/2003 10:44:56 .r~ ~ ~ ~PHILLIPS Ala~Ka, Inc. II!¡jII A S""~OIy" PHIlliPS PETHOlEUM COMPANY 3K-22 NIP (524-525,- 00:4.500) TUBING - (0-4677. 00:4.500, 10:3.833) SLEEVE - (4627-4628, 00:4.500) SURFACE -- (~7, 00:7.625, Wt29.70) PKR- (4677-4678, 00:6.750) UNER - (4677-11175, 00:4.500, Wt12.60) NIP- (9101-9102, 00:3.833) Perl (9195-9450) Perf (9675-9826) Perf (9933-10170) Perf (10345-10470) Perl (1 ()685.1 0855) Perf - (10915-10930) - Perf (10960-11060) COLlAR (11111-11112, 00:3.810) Fill (11075-11175, 00:4.500) KRU API: 500292275900 SSSV Type: NIPPLE Annular Fluid: Well Type: INJ Orig Completion: 5/5/1997 Last WIO: 3/18/2001 Angle @ TS: 70 Angle @ TD: 93 Rev Reason: ImO Last Update: 1/612002 Reference Log: Ref Log Date: LastTag: 11904(junk) TD: 11180ftKB LastTagDate: 7/15/1999MII!<HoleAn9Ie:.94deg~10788 ".. . O,I$IÕ'tj':SmUgit¡M1.;i¡¡j¡'¡;¡¡¡¡ji;,ii,i¡¡¡,', ...'jj¡¡¡¡¡¡¡¡¡¡¡¡;ill:¡¡¡¡¡¡¡¡,¡,¡¡¡g¡¡¡¡¡¡!¡¡¡¡¡¡¡¡¡¡,¡¡¡¡¡¡¡¡;.i.iŒ!¡¡¡¡¡¡iii!¡¡¡¡i,ý¡!¡i:ii¡¡:¡¡¡¡¡¡¡¡i¡¡¡i¡¡¡iiii'¡¡¡¡¡¡¡;i'¡¡' Description 'Size CONDUCTOR 16.000 SURFACE 7.625 LINER 4.500 "'" Interval 9195 - 9450 6637 - 6651 9675 - 9826 6656 - 6651 9933 -10170 6652 - 6669 10345 -10470 6684 - 6688 A-2 10685 .10855 6687.6677 10915-10930 6674 - 6673 10960. 11060 6671 - 6667 Top Bottom TVD Wt Grade Thread 0 121 121 62,50 H-40 0 4887 4091 29.70 L-80 4677 11175 6661 12.60 L-80 NSCT Wt Grade Thread 12.60 Date Type 5/5/1997 IPERF SWS 27/8. HSD; 60 deg. phasing 151 4 5/5/1997 IPERF SWS 27/8. HSD; 60 deg. phasing 237 4 5/5/1997 IPERF SWS 27/8. HSD; 60 deg. phasing 125 6 5/511997 IPERF SWS 2 718. HSD; 60 deg, phasing 170 6 515/1997 IPERF SWS 2 718. HSD; 60 deg, phasing 15 6 515/1997 IPERF SWS 27/8. HSD; 60 deg. phasing 100 6 51511997 IPERF SWS 2 718. HSD; 60 deg. Depth TVD 524 523 4627 3885 4677 3925 9101 6630 11075 6666 . 11111 6664 Description Type NIP SLEEVE PKR NIP FILL COLLAR ID 3.813 3.813 3,812 3.750 3.000. 3.000 Cameo 'DB' Nipple NO GO Cameo 'CM' Sliding Sleeve wI Cameo 'X' Selective Profile Baker'SABLMIZXP' Cameo 'DB' Nipple NO GO All following CTDU millout, from eollapse of walls 3/18/01 BAKER DOUBLE FLOAT VALVE COLLAR 3/18/01 Date 3/1812001 CTDU milled down to 11175, but fill collapsed into hole, to PBTD, PBTD @11075' at bottom of milled out shoe 12/9/2001 WAIVERED WELL - monobore completion, water injection only A'ITf'\Cl-\ TO', M \ r Ktê-l1 3~-d-~A 4-1-03 JJ,'tls Pearl No.1 P&A ~ ~, Subject: Pearl No.1 P&A Date: Wed, 9 Apr 2003 14:53:11 -0800 From: "Buster, Larry W" <lbuster@unocal.com> To: <winton_aubert@admin.state.akus> Winton, I would like to request a change to the proposed Pearl P&A Procedure as follows: Change the circulation squeeze depth (shooting holes thru the 3-1/2" tubing) from +1- 1200' to +1- 870'. The reason for the change request is our concern with shooting into a sand and/or coal of which there are numerous between 900' to 1200' in this well. We feel shooting into a sand could induce losses while performing the cement job and affect our ability to circulate cement to surfaGe. Regards, Larry W. Buster Drilling Enginee:r Unocal Alaska (907) 263-7804 - Office (907) 263-7884 - Fax (907) 351-6730 - Mob. Re: Pearl #1 P&A ~ ~ Subjec1t: Re: Pearl #1 P&A Dat(!: Tue, 08 Apr 2003 16:30:10 -0800 From: Winton Aubert <Winton_Aubert@admin.state.akus> Organization: AOGCC To: "Buster, Larry W" <lbuster@unocal.com> Larry, AOGCC hereby approves proposed changes to the Pearl #1 abandonment (App. No. 303-104) as described in the attached. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 "Buster, Larry W" wrote: Winton, It has been a while since we have talked, hope all is well. The Pearl #1 P&A as presented and approved by the AOGCC called for "bullheading" cement down the 7" x 9-5/8" annulus. However, we have been unable to establish injection into the formation even after going up to 1850 psi surface pressure (30.0 ppg EWM at the ~)-5/8" shoe). It appears we brought cement up into the 7" x 9-5/8" during the primary cement job - isolating us from the formation below. To deal with this change, I have attached a proposed alternative abandonment plan (and schematic) which will allow us to circulate cement into the 7" x 9-5/8" casing annulus after perforating thru to casing strings at :J.ZðtT'. .If- .g.7()~ ~C!!.'- We have already successfully pumped cement down the 3-1/2" tubing string and pressure tested the plug with your inspector present (as per the original program). We have currently suspended the abandonment work until final agreement of the plan forward, but would like to re-start the operation tomorrow morning if possible. «Pearl Proposed Aband Schematic..doc» «Pearl #1Alternative P&A Summary.doc» Larry W. Buster Drilling Engineer Unocal Alaska (907) 263-7804 - Office (907) 263-7884 - Fax (907) 351-6i'30 - Mob. ELEVATION: 222.5 Feet ACTUAL RKB = 17.37 Driven 13-3/8" 95' 9-5/8" @ 1791' Cemented to Surface Cement from 3700' to 3000' 2 3 4 :; ,-..,. 1 ~UTH NINILCHIK nell PEARL # 1 Actual Completion 3/29/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surface 95' 9-5/8" 47 L-80 Butt 8.681 Surface 1,791' T' 26 L-80 Butt Mod. 6.276 Surface 4,445' T' PES 26# L-80 Butt Mod 6.184 5103' 5106' Cmtr T' 29 L-80 Butt TKC 6.184 4,445' 8,000' Tubing 3-1/2" 9.2 L-80 Butt SC 2.992 Surface 3,788' 3/8" .25 416SS Continuous .25 Surface 1,968' JEWELRY DETAIL OD Item 11" Tubing Hanger, 3-1/2" 5.437 Chemical Injection Mandrel SAB 40-32 Baker Packer "XN" Nipple Shear Out Ball Sub w/ W /L Entry Guide NO. Depth ID 1 17.37' 2.992 2 1968' 2.990 3 3706' 2.990 4 3,754' 2.661 5 3788' 2.990 6 1968' Date Zone Top 3/19/02 7800 7798' 3/25/02 7300 7289' 3/28/02 5700 5694' 3/29/02 4000 4008' Methanol Injection Line Perforations BTM Length 7836' 36' 7319' 30' 5734' 40' 4043' 35' Comments 2", PI, 6spf, 60 deg 2", Pl, 6spf, 60 deg 2", Pl, 6spf, 60 deg 2", Pl, 6spf, 60 deg Perfs 4000'- CEMENT HISTORY 4008' Date String Size Depth Volum Comments e of Cement from Cmt 3800' to 5734' 2/20/02 Surf 9-5/8" 1791' 122 Cement Circulated to Surface with BBLS 40+ BBLS Perfs 3/07/02 Prod 7" 8000' 100 FIRST OF TWO STAGE JOB 5694' - BBLS WITH DV TOOL AT 5103'. 5734' TOC STAGE 1 AT DV TOOL 3/08/02 Prod 7" 8000' 70 SECOND STAGE JOB BBLS TOC EXPECTED AT 2700'. 3/29/02 4000 4008' 4043' 35' 2", Pl, 6spf, 60 deg Perfs 7289' - 7319' EI PEARL # 1 tLUHLU PBTD = 6,945' ELM TD = 8,000' Vertical Plug at 7755', TOC = 7730' Perfs 7799'-7835' DRAWN BY: LWB REVISED: 4/8/03 ~ ,-., UNOCAL8 Well Pearl #1 P& A Operation Program Summary . Fill tubing and casing annulus volumes with water and establish injection rates. (DONE) . Mix and bullhead 73 bbls of 12.5 ppg cement down tubing and displace to the end of the tubing with water. (DONE). . Allow cement plug to set up for 12 hours prior to testing to 1500 psi for 30 minutes (charting and give notice to AOGCC to witness). (DONE) . RIH with tubing punch to 3,700' and punch holes in 3-1/2" tubing. / . Establish circulation and balance a 700' plug (25 bbls) of 12.5 ppg cement from 3,700' to 3,000' both inside the 3-1/2" tubing and within the 3-1/2" x 7" casing annulus. /~ . Allow cement plug to set up for 12 hours prior to testing to 1500 psi for 30 minutes / (charting and giving notice to AOGCC to witness). . R/U perforating guns and RIH to +/- 1,200'. Perforate thru 3-1/2", 7" and 9-5/8" casing, ,-- . Establish circulation and circulate both 3-1/2" x 7" and 7" x 9-5/8" casing annulus clean. /" . Mix and pump 12.5 ppg cement (approx. 73.0 bbls) down 3-1/2" tubing and both 3-1/2" x 7" and 7" x 9-5/8" casing annulus until cement returns are to the surface. . Allow the cement to set up for 12 hours prior to testing to 1500 psi for 30 minutes, /' (charting and giving notice to AOGCC to witness). . Cut off wellhead 4' below ground level and cap with marker post as required in AOGCC ./ regulations. Program Summary Pearl #1 P&A Procedure 418/2003 . . r--.. r--.. ) UTH NINILCHIK Well PEARL # 1 P&A COVER LETTER 3/29/03 .. - <- UNOCAL8 Friday March 28, 2003 Consultant Drilliing Engineer Jim Mosley Mr. Dan Seamount, Commissioner AOGCC 333 West yth Ave., Suite 100 Anchorage, Alaska 99501 Sundry Notice of Plug and Abandonment South Ninilchik Prospect PEARL Well No.1 East Side, Kenai Penninsula Dear Commissioner Seamount, Enclosed is a Sundry Notice for Plugging and Abandoning the Pearl # 1 well (AOGCC Form 10-403). The subject well is identified as the Unocal South Ninilchik Prospect, Pearl Well No.1. AOGCC Permit to Drill # 202-011 with an API number 50-133-20509-00. The subject well was drilled and tested as a dry hole during the 2002 drilling campaign. Please find enclosed a proposed procedure to plug and abandon the subject well. The anticipated start date for this plugging and abandoning work is April 7th, 2003. If you have any questions, please do not hesitate to call Jim Mosley at 263-7679. Si.nce~ ~ Mosley Consultant Drilling Engineer Unocal, Alaska R... r:C' e . \,i"". ' . i1..- , '-0 = MAR 2 " / U AlailaQa& G~Cons, Q:!í¡¡¡ìi3sion kì;~eøe PEARL # 1 ORIGtN'AL DRAWN BY: J.I.M. REVISED: 3/26/03 JIM ~ \ó-JC:t.1\- ~/2.tl2-005 ~ 0(7'.3 03(2f?/O '> ) UTH NINILCHIK ~f'1x1 tÆ(e57 --.....) Well PEARL # 1 r/(, TABLE OF CONTENTS 3/29/03 . UNOCAL8 AOGCC FORM 10-403 SUNDRY NOTICE OF PLUG AND ABANDONMENT 1. Type of Request: Abandon: L Suspend: - Alter casing: Repair well: Change approved program: Pull tubing: Operation shutdown: - Re-enter suspended well: Plugging: L Time extension: Stimulate: Variance: Perforate: Other: 5. Type of well: 6. Datum elevation (DF or KB) Development: - 17.37 RKB to GL Exploratory: X 7. Unit or Property name Stratigraphic: South Ninilchik Prospect Service: Pearl # 1 8. Well number Pearl # 1 9. Permit?ber 202-011 10. API number 50- 133-20509-00 11. Field/Pool South Ninilchik Prospect feet 2. Name of Operator Union Oil Company of Califonia (UNOCAL) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1568' FNL, 196B' FWL SEC 24, T01S, R14W, SM AK At Top of Test Perforations 1568' FNL, 196B' FWL SEC 24, T01S, R14W, SM AK At Total Depth 1568' FNL, 196B' FWL SEC 24, T01S, R14W, SM AK 12. Present well condition summary Total depth: measured true vertical 8000' feet 8000' feet Plugs (measured) See Attached Drawings Effective depth: measured true vertical 8000' feet 8000' feet Junk (measured) Nonel See attached Drawings Length ;];21 ~ Perforation depth: measured First Test 1'798 to 7836' ; Second Test 7289 to 7319' ; Third Test 5694 to 5734' ; Fourth Test 4008 to 4043' true vertical Casing Structural Surface Size Cemented Measured depth True vertical depth 13-3/8" N/A Driven 95' 95' 9-5/8" 302 lead & 230 Tail 1791' 1791' 7" 560 sxs Stage 1 & 7983' 7983' 330 Sxs Stage 2 Production Uner Same as Measured Tubing (size, g~3de, and measured depth) 3-1/2" 9.2 Iblft L-80, Imp Butt From 0 to 3788' 3/8" Chemical injection control line from 0 to 1968' Packers and SSSV (type and measured depth) (See Attachment) BAKER SAB 40-32 @ 3706' 13. Attachments L Description summary of proposal: L Detailed operations program: Three Well bore: Schematics (Current, Proposed plugging, and Abandonment marker), P&A Procedure. 14. Estimated date for commencing operation 15. Status of well classification as: 04/07/2003 16. If proposal well verbally approved: BOP sketch: Oil: Gas: Suspended: 4:' Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. t.. ...,. - It W tV 'i1f'1rVtl'J .oil \ l-411Ì " Signed: f'Y"\ f rf\'/rõJ.JlJlAI,'Iy Title: grilling "'Mogar .W'G,.vW- U FOR COMMISSION USE ONLY Conditions 0 approval: Notify Commission so representative may witness X Plug integrity~ BOP Test- Location clearance- Mechanical Integrity Test- Subsequent form required 10- t.f 0 '7 Date:3/1tif J ö'3 IAPpro~~?1 JD4 Approved by order of the Commissioner ;e... -7 ~ ~ C~m;";oo" RBDMS 8Ft ORIGINALAPR o,w OV~3 PEARL # 1 InEtXWN BY: J.I.M. REVISED: 3/26/03 JIM .~ .~ )UTH NINILCHIK Well PEARL # 1 T ABLE OF CONTENTS 3/29/03 UNOCALe TABLE OF CONTENTS AOGCC FORM 10-403 SUNDRY NOTICE OF PLUG AND ABANDONMENT.................................................................................. 2 PEARL # 1 WELLBO RE SCHEMA TI C .................................................................................................................................................... 4 WELL HIS TO R Y SUMMARY................................................................................... ............................... .............. ....... ..... ..... ..... .............. 5 P &A PLUG S UI\-IMAR Y ............................ .............................................. ..... .............................. ...................... .............. ....... ............... ....... 5 20 AA C 25.120 "'ELL ABANDO NMENT MARKE R ........................... ....... ....... ..................... ......................... .... ..... .............. ............ ..... 5 P L U GG IN G AN]!) ABANDONMENT P R OCED URE ................................................................ ............... .......... ......... ....... .............. ........ 6 PERFORM TOF' JOB ON 7" BY 9-5/8" ANNUL US ................................................................................................................................. 6 PERFORM BUl,LHEAD SQUEEZE OF PRODUCTION PERFORATIONS ....................................................................................... 6 PERFORATE HIE TUBING AND CEMENT THE PRODUCTION TUBING IN PLACE................................................................. 7 INSTALL CAPS AND MARKER POST .................................................................................................................................................... 7 CLEAR LOCATION AND CLOSE RESERVE PIT ................................................................................................................................. 7 PROPOSED PEA.RL # 1 ABANDONMENT CONFIGURATION .......................................................................................................... 8 PROPOSED PEARL # 1 WELLBORE CONFIGURATION WITH P&A PLUGS IN PLACE............................................................9 PEARL # 1 DRAWN BY: J.I.M. REVISED: 3/26/03 JIM .. Date String Size 4000'- 2/20/02 Surf 9-5/8" 4008' 3/07/02 Prod 7" TOC ON STAGE 1 @ 5100' 3/08/02 Prod 7" 3/22/02 Test 2" Perfs HSD6 SPF 3/26/02 Test 2" Perfs HSD Perfs 6SPF 7289'- 7319' ~ . - UNOC:AL8 PEARL # 1 WELLBO RE SCHEMA TI C ELEVATION: 222.5 Feet ACTUAL RKB = 17.37 1 , Driven 13-3/8" 95' 9-5/8" @ 1791' Surface Top of Cement 2003' if Guage 0 2 @ 2853' - ifWO 30% ! CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 61 K-55 Butt 12.515 Surface 95' 47 L-80 Butt 8.681 Surface 1,791' 26 L-80 Butt Mod 6.276 Surface 4,445' 26# L-80 Butt Mod 6.184 5103' 5106' 29 L-80 Butt TKC 6.184 4,445' 8,000' 9.2 L-80 Butt SC 2.992 Surface 3,788' .25 416 SS Continuous .25 Surface 1,968' JEWELRY DETAIL NO. Depth ID OD Item I 17.37' 2.992 II" Tubing Hanger, 3-1/2" 2 1968' 2.990 5.437 Chemical Injection Mandrel 3 3706' 2.990 SAB 40-32 Baker Packer 4 3,754' 2.661 "XN" Nipple 5 3788' 2.990 Shear Out Ball Sub wi W IL Entry Guide 6 TED Methanol Injection Line Perforations Date Zone Top BTM Length Comments 3/19/02 7800 7798' 7836' 36' 2", PI, 6spf, 60 deg 3/25/02 7300 7289' 7319' 30' 2", PI, 6spf, 60 deg 3/28/02 5700 5694' 5734' 40' 2", PI, 6spf, 60 deg 3/29/02 4000 4008' 4043' 35' 2", PI, 6spf, 60 deg SIZE 13-3/8" 9-5/8" 7" 7" PES Cmtr 7" Tubing 3-1/2" 3/8" Perfs 7799'-7835' TD = 8,000' PEARL # 1 .~ )UTH NINILCHIK Well PEARL # 1 Actual Completion 3/29/03 CEMENT HISTORY Depth Vol of Comments Cmt 1791' 122 Cement Circulated to Surface with BBLS 40+ BBLS 8000' 100 BBLS FIRST OF TWO STAGE JOB WITH DV TOOL AT 5103'. TOC STAGE 1 AT DV TOOL SECOND STAGE JOB TOC EXPECTED AT 2700'. Set Posiset Plug and Dump Bailed cement from 7755' to 7729' 8000' 70 BBLS TOC @ 25' = 7729' I BBL TOC @ 27 6945' BBLS Placed cement with Coiled Tubing. Tested Plug to 1750 psi. DRAWN BY: J.I.M. REVISED: 3/26/03 JIM ~ .~ ) UTH NINILCHIK Well PEARL # 1 PROPOSED P&A UNO'~ALe WELL HISTORY SUMMARY / The Pearl well was drilled as a vertical well in 2002 to a depth of 8000'. Four zones were perforated and tested dry. It is proposed to abandon the well leaving the tubing in place as per the following recommendation. The casing strings that were set on this well included: 13-3/8" Driven to 95' 9-5/8" Cemented to surface from 1791' r- 7" Two stage cemented from 8000' to 5100' on stage one and from 5100' to somewhere between 2800' and 2000'. It is not believed that the cement reached the shoe of the surface casing. The hole for the 7" was drilled with water base mud to a depth of 5000' and from 5000' to TD with oil based mud. The second stage cement was preceded ~h only 30 bbls of mud push so the 7" by 9-5/8" annulus contains some 30 bbls of mud push and about 30 bbls of oil base mud. The shoe of the 9-5/8" casing is believ€:d to be open to the annulus and thus will require that the 7" Casing annulus be squeezed. It will b:-vroposed that this annulus be squeezed from the top down with 75 bbls of cement prior to the abandonment of the inner strings. The cement in the 7" by 9-5/8" annulus will be displaced to 10 feet below ground level to facilitate casing cutting and abandonment. Cement will be left inside each string and a plate will be welded across the top of the outer string of casing. A marker pole will be erected on /' top of the abandonment plate. P&A PLUG SUMMARY 1. The bottom test zone was plugged with a Posiset Plug set at 7755' and with 25 feet of cement dump bailed on top ofPosiset. Top of cement plug # 1 is at 7729'. SET ON 3/22/02 ,/ 2. The second set of Test Perfs was plugged with 27 bbls of cement placed with coiled tubing. Top of cement plug # 2 is 6945'. SET ON 3/26/02 ~ 3. The third cement plug to be set will be to squeeze the backside of the 7" wi 76 bls of 12.5 ppg cement. 4. The fourth Cement plug to be set will be to fill the 7" BQV{ the packer and t 11 pipe thus cementing the two sets of perforations that are currently open. This plug will us ~. ... bls of 12.5 ppg cement and leave the top of cement just below the tailpipe at 3788'. . 5. The fifth plug to be set is to fill the 7" and 3-~/2~?):... õ e the existing packer with cement. Perforations in the tubing are required and the cement volume needed will ~bls of 12.5 ppg cement. The top of cement will be just below ground ~L / NOTE: The total amount of cement needed will be 278 bbls of 12.5 ppg cement. 20AAC 25.120 WELL ABANDONMENT MARKER (a) The exact location of an abandoned well must be shown on a steel marker as per (b) below or (c) if at the request of the surface owner using a marker post as per (c) below: (b) A marker plate must be 1. at least y.¡" thick 2. at least 18" square or in diameter 3. Welded to and must cover the outennost casing string ( c) A marker post must: 1. Be at least 4 inches in diameter and at least 10 feet long 2. be set in cement inside the well casing or welded to the top of a steel plate secured to the casing head or casing stub 3. extend from 4 to 6 feet above final ground level 4. Be closed at the top with cap, welded plate or cement (d) The following infonnation must be bead welded to the marker plate or post: 1. Name of Operator UNOCAL 2. Pennit to Drill Number AOGCC PTD # 202-011 j' 3. Name of the well PEARL # 1 4. API number of the well API # 50-133-20509-00 PEARL # 1 3/26/03 JIM ~ ~ . ) UTH NINILCHIK Well PEARL # 1 PROPOSED P&A PROCEDURE . - .. - UNOI:AL8 PLUGGING AND ABANDONMENT PROCEDURE PERFORM TOP JOB ON 7" BY 9-5/8" ANNULUS 1. Mow in and layout liner material on the ground as needed to prevent any spills during the P&A operation. The equipment needl~d will include the following during the P&A: 1 RV living quarters, 1 batch cement mixing unit, 1 high pressure skid mounted cement pump, two cement silos, one 500 bbl water tank, one electric or diesel driven 3" water pump, Vacuum Trucks, SuperSucker Trucks, Parking Areas for vehicles, Iron racks, APRS Electric line Unit, lubricator, small test pump, Tubing punching tools, one squeeze manifold, sufficient chicksan for flowlines, 1 mud mixing tank with compartment for reversing, and a small light plant for lights and etc. 2. Movl~ in RV, Cementing equipment, silos, cement, tanks, test pump, light plant, and vacuum truck(s) as needed. 3. Rig up to pump on the T' by 9-5/8" Annulus. Test lines to 2000 psi. / 4. Prepare to run injection test on the 7" by 9-5/8" annulus using water from the reserve pit as the injection fluid. 5. Establish pump rates and pressures injecting down the 7" by 9-5/8" annulus. Do not initially exceed 500 psi or 6 BPM. Contact Anchorage Drilling Engineer (Jim Mosley) or Drilling Supt (Evan Harness) f~nstructions should the annulus not accept fluids at a pressure below 500 psi or behave in some other unexpected manner. Anticipate that the shoe will require at least 12.5 ppg equivalent pressures to establish injection. The FIT on the 9-5/8" Casing shoe was run with 9.0 ppg fluid and jug tested to 325 psi. This equates to a shoe integrity g£~least (9.0)(.052)(1791) +325 = 1163 psi. NOTE: The Griner well in Anchor point exhibited a fracture gradientpf20J1)pg at a similar depth. Record and chart the pressure it takes to establish injection and forward this to the drillin~éer prior to proceeding with the cement job. What we are looking for is the ability to inject at or below fracture pressures. The shape of the pressure up curve should indicate whether injection at below fracture pressure is possible. Do not exceed 500 psi without discussion with Drilling Engineer. ./ 6. NOTIFY AOGCC OF PLUG SETTING TIMING SO THAT AOGCC CAN WITNESS IF THEY SO CHOOSE. ----- 7. The volume of cement required to fill the 7" by 9-5/8" annulus is calculated as follows: [(8.681 )(8.681)- (7)(7)](.0009714)(1791) = 45 bbls. It is anticipated that the well may be drinking some cement iffracturing has occurred or if cement goes downhole. The annular volume from the casing shoe to the suspected top of Cement around 2500 feet is calculated as follows: [(8.5)(8.5)-(7)(7)](.0009714)(2853-1791)(1.3) = 31.18 bbls. The total cement planned is 45+31 = 76 bbls. This will fill the backside to the top of cement based on a 30% washout and based on the well taking fluids at the /' bottom of the uncemented interval. If the well does not take fluids readily, then it will be necessary to fracture squeeze the 9- 5/8" shoe with the extra 31 bbls. 8. AfteJr establishing an acceptable injection rate and pressure, mix and bullhead 76 bbls of 12.5 ppg cement into the T' by 9- 5/8" annulus. Attempt to maintain at least a 4 to 5 BPM pump rate. Follow cement with 1 bbl of water leaving the top of the cem<mt just below ground level to facilitate cutting the casing off after the P &A is complete. /- 9. Shut down cementing, holding whatever pressure was shut in and observe annulus pressure versus time. Record at 1 minute, intervals for first ten minutes and at 30 minute intervals therafter for the first 4 hours. It is intended that the annulus stand / full. NOTE: THE 9-5/8" SHOE WAS JUG TESTED TO 12.5PPG. The Surface casing was cemented to the surface with 12.5 ppg cement. 10. Wait on cement for 12 hours and test 7" by 9-5/8" Annulus to 1500 psi. / PERFORM BULLHEAD SQUEEZE OF PRODUCTION PERFORATIONS 11. Install Pump in sub with valve on top of tree and line up to pump on 3-1/2" Tubing. Test lines to 3000 psi and establish pump in rates and pressures. Do not exceed 2000 psi down the 3-1/2" tubing. There are two sets of perforation open below the e:xisting SAB packer set at 3706'. It is desired to fill the casing below the tailpipe to the bottom open perforation with ceffil~nt. Note that there are two weights ofT' casing below the tailpipe. The volume ofT' below the tailpipe to the bottom perforations at 5734' is calculated a.Y.f~llows: (6.184)(6.184)(.0009714)(5734-4445) + (6.276)(6.276!(.0009? 1 4)(4445- 3788) = 47.88 + 25.14 = 73 BBLS. MIX and bullhead 73 bbls of 12.5 ppg cement down the productIon tubmg followed by a displacement equal to the depth of the bottom of the tailpipe plus 1 bbl to ensure that the tailpipe is cleared. The tubing volume to use for displacement is calculated as follows: (2.992)(2.992)(.0009714)(3788) + 1 = 33.9 BBLS. Ensure that there is a hand pump tied into the 3/8" Control line and continuously pump fresh water through the control line while pumping cement into and through the 3-1/2" Tubing. This will ensure that the 3/8" Control line stays open as it will also be plugged as a part of the last plug setting during the P&A. ./' Record the test wI.th a chart recorder. 12. Wail on cement 12 hours and test the bullhead squeeze job to 1500 psi for 30 minutes. 13. Prepare to perforate the tubing and cement the tubing in place. PEARL # 1 3/26/03 JIM ~~ UNOI:ALe ----. -------- )UTH NINILCHIK Well PEARL # 1 PROPOSEDP&APROCEDURE PERFORATE THE TUBING AND CEMENT THE PRODUCTION TUBING IN PLACE 14. Rig up APRS Eline. Test lubricator to 1000 psi and run in the hole with a tubing punch gun loaded for two feet with. Perforate 8 holes in the production tubing starting just above the production packer. Perforate 4 holes per foot from 3700 to 3698. Pull out of hole and rig down APRS. ;../ 15. Establish circulation rates and pressures. Record circulating pressures at 3, 4, 5, and 6 BPM through the perforated holes in the tubing taking returns out the 7" casing. Upon obtaining satisfactory cirdculation rates, prepare to cement. Rig up sque~ze manifold and lines as needed to reverse or circulate. The reversing capability will be needed to place 0.25 bbl of water in the annulus to facilitate the cutting of casings just below the ground level. NOTE: Be sure that the hand pump on the 3/8" Control has been checked to ensure that the 3/8" control line is still open. During the cementing of the tubing in plaœ, the control line will be plugged with pure cement. 16. Rig up to take returns from the 3-1/2" by 7" Annulus. The annular volume between the 7" and the 3-1/2" casing from the packer to the surface is calculated as follows: [(6.276)(6.276)-(3.5)(3.5)](.0009714)(3700) = 97 bbls of cement. The tubing volume is calculated as follow~2.992)(2.992)(.0009714)(3700) = 32.1 bbls of cement. The sum ofthe annular and tubing volumes is 97+32 = 129 bbls of cement. Mix and pump 129 bbls of 12.5 ppg cement followed by 0.5 bbls of water to /'" displace the cement top inside the tubing below the wellhead by 0.5 bbls. Have onhand sufficient pure cement to plug the control line. Mix and retard the cement for the control line in a 5 gallon bucket at 12.5 ppg. Use hand pump to fill the 3/8" Control line with cement. The control line holds some 5 gallons to the injection port. Ensure that the control line is filled with cement. Allow well to equalize and rig up to reverse circulate. Reverse 0.25 bbl of water into the annulus while taking returns from the tubing. Shut down and allow the well to stabilize. Ensure that there is water in the top of both strings to facihtate cutting casings off just below the ground level. ./"" 17. Wail on cement 12 hours and test both the 7" annulus and the 3-1/2" tubing with 1500 psi. Record both tests with a chart recorder. This concludes the plugging portion of the P&A. INSTALL CAPS AND MARKER POST 17. Unflange and set tree off. Send Tree to Cameron for inspection and repair. 18. Cut off the wellheads and flush cut the casings to 4 feet below the ground level. Send wellheads with stubs in place to Cameron in Anchorage for stub removal, slip redressing and general refurbishment. Cap the control line with a bullplug swagelock fitting. Ensure that the cement top is equal to the cutoff depth on all strings. Use readimix to top off the annuli as needed. 18. Make final cuts on the 3-1/2", 7", 9-5/8" and 13-3/8" Casings and tubing. Install plate across the top ofthe 13-3/8" as per ~ AOGCC regulations. 19. Fabricate and install permanent marker post on top of the wellhead. Attach the marker post to the top of the casing stub with a series of gussets welded around the top plate attaching the 4" Post to the cap that will be installed over the top plate. See drawing for details on marker post. CLEAR LOCATION AND CLOSE RESERVE PIT 20. Pick up the reserve pit and haul all of the contents to the Grind and Inject unit located either onsite at Pearl or on the NNA pad site. Grind and slurrify all of the cuttings. Use trucks to haul the slurrified cuttings to the NNA location. Dispose of the Pearl Reserve pit into the NNA annulus. NOTE: THIS IS BASED ON THE ASSUMPTION THAT THE NNA WELL HAS BEEN APPROVED FOR PEARL DISPOSAL. CONTACT DRILLING ENGINEER TO VERIFY APPROVAL HAS BEEN OBTAINED. IF NO APPROVAL HAS BEEN OBTAINED, AN AL TERNA TE PLAN AND DISPOSAL LOCATION WILL BE GIVEN. 21. After the reserve pit is emptied, clean up the location and pick up the reserve pit liner. Dispose of the liner via the local landfill. 22. Back fill and level the reserve pit. 23. Reseed the area to prevent erosion. 24. Have the AOGCC witness that the reserve pit is closed and that the location has been cleared to the satisfaction of the AOGCC. Obtain location clearance paperwork from the State. /' PEARL # 1 3/26/03 JIM A ,. UNOC:AL8 ~ ~ ) UTH NINILCHIK Well PEARL # 1 PROPOSED P&A MARKER PROPOSED PEARL # 1 ABANDONMENT CONFIGURATION / +-- Ground Elevation 225.8' --~ 4'BGL 13-7/16" ID Cap to fit over 13.')/8". Cap to be welded to 13..3/8" Casing with gusset plates attaching cap and marker po:;t PLUG # 3 GOES INTO T' BY 9-5/8" ANNULUS PLUG # 4 IS BULLHEADED BELOW PACKER VIA 3-1/2" TUBING PEARL # 1 ~ 4" Diameter Post with welded cap ~ .. c::> c::> I CI\ c::> IF¡ c::> M I .... M ""....M ~9=11:'7 <~~~ UM~=II: OQ<- Z¡...¡..;¡=- ~=-=-< Top of Marker to be 6 Feet /' Above Ground Level .. /' .. ~ ... ............. I Gussets Cut all Tubulars at 4 feet below ground level. Install Plate on 13-3/8" and Install Marker Post / PLUG # 5 IS CIRCULATED INTO T' AND FILLS T' AND 3-1/2" TUBING ABOVE PACKER 9-5/8" Surface Casing T' Production Casing 3-1/2" Tubing ---------- 3/26/03 JIM r - UNOI~AL. ,-.... ~, ) UTH NINILCHIK Well PEARL # 1 PROPOSED P&A PLUGS PROPOSED IÞEARL # 1 WELLBORE CONFIGURATION WITH P&A PLUGS IN PLACE ELEV A nON: 222.5 Feet CASING AND TUBING DETAIL GRADE CONN ID K-55 Butt 12,515 L-80 Butt 8.681 SIZE WT ACTUAL RKB =: 17.37 13-3/8" 61 9-5/8" 47 7" 26 7" PES 26# Cmtr 7" 29 Tubing 3-1/2" 9.2 3/8" .25 NO. Depth 1 17.37' 2 1968' 3 3706' 4 3,754' 5 3788' 6 TBD Date Zone 3/19/02 7800 3/25/02 7300 3/28/02 5700 3/29/02 4000 TD = 8,000' PEARL # 1 TOP Surface Surface BTM. 95' 1,791 ' L-80 Butt Mod 6.276 Surface 4,445' L-80 Butt Mod 6.184 5103' 5106' L-80 Butt TKC 6.184 4,445' 8,000' L-80 Butt SC 2.992 Surface 3,788' 416 SS Continuous .25 Surface 1,968' 2" TOC @ 27 6945' BBLS ID 2.992 2.990 2.990 2.661 2.990 JEWELRY DETAIL OD Item II" Tubing Hanger, 3-1/2" 5.437 Chemical Injection Mandrel SAB 40-32 Baker Packer "XN" Nipple Shear Out Ball Sub wi W/L Entry Guide Methanol Iniection Line Perforations BTM Length 7836' 36' 7319' 30' 5734' 40' 4043' 35' Top 7798' 7289' 5694' 4008' Comments 2", PI, 6spf, 60 deg 2", PI, 6spf, 60 deg 2", PI, 6spf, 60 deg 2", PI, 6spf, 60 deg CEMENT HISTORY Date String Size Depth Vol of Comments Cmt 2/20/02 Surf 9-5/8" 1791' 122 Cement Circulated to Surface with BBLS 40+ BBLS 3/07/02 Prod 7" 8000' 100 BBLS 3/08/02 Prod 7" 8000' 70 BBLS 3/22/02 Test 2" TOC@ 25'= Perfs HSD6 7729' I BBL SPF Perfs 7289' - 7319' 3/26/02 Test Perfs Plug # 1 Posiset with 25' cement dump bailed to 7729' Perfs 7799'-7835' HSD 6SPF / FIRST OF TWO STAGE JOB WITH DV TOOL AT 5103'. TOC STAGE 1 AT DV TOOL SECOND STAGE JOB TOC EXPECTED AT 2700'. PLUG # 1 Set Posiset Plug and Dump Bailed cement from 7755' to 7729' PLUG # 2 Placed cement with Coiled Tubing. Tested Plug to 1750 psi. 3/26/03 JIM d w-o/ I ~ ~ .;a ... Unocal Alaska 909 W. 9th Avenue Anchorage, AI< 99501 Te1e: (907) 263-7651 Fax: (907) 263-7828 E-mail: hanisonb@unoca1.com UNOCAL8 September 23, 2002 Beverly Harrison Business Ventures Assistant To: AOGCC Lisa Weerie . 333 W. 71 Ave. Ste#100 Anchorage, AK 99501 DA TA TRANSMIITAL - -~..t~~Ì'~:lI"dll " A-29RD ADN DIP DATA v' A-29RD ADN DIP DATA V A-29RD ADN DIP DATA V A-29RD JlDN DIP DATA V A-29RD CEMENT BOND LOG I GR I CCL V A-29RD CEMENT BOND LOG I GR I CCL ¡/ A-29RD CEMENT BOND LOG I GR I CCL v ~ A-29RD CEMENT RETAINER CASING PUNCHER V '8 A-29RD CEMENT RETAINER CASING PUNCHER V \ A-29RD EPOCH FINAL WELL REPORT WI FORMATION LOG .,/' ~ A-29RD . EPOCH FINAL WELL REPORT WI FORMATION LOG V" r'(j A-29RD I:POCH FINAL WELL REPORT WI FORMATION LOG V A-29RD MWD/GR MD COMPOSITE FIELD PRINT V A-29RD PERFORATION DEPTH CONTROL MEMORY GR I CCL V A-29RD IJERFORATION DEPTH CONTROL MEMORY GR I CCL V A-29RD IJERFORATION RECORD 2 7/8' PJ HSD 6 SPFV A-29RD :>ERFORATION RECORD 2 7/8' PJ HSD 6 SPF v A-29RD SCHLUMBERGER FORMATION EVALUATION LOGS v --.. A-29RD VISION SERVICE MD COMPOSITE FIELD PRINT V , ira'005 D-15RD2 PL ADVISOR /INJECTION PROFILE MEMORY PL T W/FLOVIEW v - J D-15RD2 PL ADVISOR I INJECTION PROFILE MEMORY PL T W/FLOVIEW v DI-15 COMPLETION RECORD 2' HSD, POWER JETS v DI-15 COMPLETIONRECORD2'HSD,POWERJETS v DI-16 COMPLETION RECORD 2' HSD, POWER JETS ¡,/ DI-16 COMPLETION RECORD 2' HSD, POWER JETS / G-12RD3 COMPLETION RECORD 10' CEMENT PLUG v G-12RD3 COMPLETION RECORD 10' CEMENT PLUG V"" G-12RD3 COMPLETION RECORD 2.5' HSD PJ V "~:~~~~:~~-:~-u.~:;~ 8/212002 12606-13220 1 B-Line 8/212002 11950-12650 1 B-Line 8/212002 12606-13220 1 CD 8/212002 12029-12713 1 CD 8/5/2002 5000-13211 1 B-Line 8/5/2002 5000-13211 1 CD 8/5/2002 5000-13211 1 Film 1680-1999 1 B-Line 1680-1999 1 Film 1786-13300 3 B-Line 1 CD 1 PAPER 1 B-Line 1 B-Line 1 Film 1 B-Line 1 Film 1 CD 1 B-Line 1 B-Line f ~ 1 CD 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 215 INCH 215 INCH 2/5 INCH 5 INCH 5 INCH 2 INCH 6/30/2002 8/112002 8/1/2002 6/30/2002 8/10/2002 8/10/2002 8/28/2002 8/28/2002 8/212002 6/30/2002 3/17/2002 3/17/2002 5/11/2002 5/11/2002 5/912002 5/9/2002 6/29/2002 6/29/2002 6/21/2002 2 INCH 2 INCH 2 INCH 5 INCH 5 INCH 1824-12685 12720-13240 12720-13240 13100-13207 13100-13207 1824-13300 9150-10050 9150-10050 11950-12555 11950-12555 9800-1077 9800-1077 13150-13608 13150-13608 13100-13696 2 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH IIp-Ol./5 ~4;oS1 \. ~ r.f) [() 9 f(j 0 <õ Ploase acknowledge receipt by signing and returning one copy of this transmittal or ~.. .'~ ~3-l~~~',~- ""'" IE- ,. - . . ~,.", ;' U ~ce;ved ~(~ Date: OCT 0;) 2002 Aia<'ka ,\;,~ Ii. (.:"", "'.. .. '" "",Ii v: v¡;¡-:;¡ ;"';.;;13. vJmmiSSion Anchorage . {2 G-12RD3 Q G-12RD3 ~ G-12RD3 ~ G-12RD3 011 K-30RD ,10- K-30RD '. LRU C-1RD LRU C-1RD ~D.D"Î \ ~~ \0 NNA-1 i)- NNA-1 \ NNA-1 a ~ NNA-1 PEARL-1 PEARL-1 PEARL-1 PEARL-1 ::::: PEARL-1 0 PEARL-1 I rt'\ . PEARL-1 a PEARL-1 '\) PEARL-1 PEARL-1 - SRU 12-15 SRU 12-15 SRU 12-15 SRU 12-27 SRU 12-27 SRU 12-27 SRU 12-27 SRU 212- 27 SRU 212- 27 - SRU 213- 10 SRU 213- 10 SRU 213- 10 SRU 213- '00 10 - SRU 213- "\ 10 f1¡ SRU 213- 10 Q SRU 213- f C5 10 SRU 213- 10 o'd-d- \\ÓÝ f\ .1\ .p ~~ .&' \ \ to I -on SRU 23-33 .--.... COMPLETION RECORD 2.5' HSD PJ ¡/" 5 INCH COMPLETION RECORD POSISET PLUG 15' CEMENT II" 5 INCH COMPLETION RECORD POSISET PLUG 15' CEMENT ../ 5 INCH COMPLETION RECORD POSISET PLUG 15' CEMENT vi 5 INCH PERFORATING DEPTH CONTROL MEMORY GR 1 CCL v 5 INCH PERFORATING DEPTH CONTROL MEMORY GR 1 CCL V' 5 INCH COMPLETION REPORT 2' HSD POWER JETS v 5 INCH COMPLETION REPORT 2' HSD POWER JETS"""" 5 INCH EPOCH MUD LOG v 2 INCH EPOCH MUD LOG ./ 2 INCH COMPLETION RECORD 2' HSD POWER JET V 5 INCH COMPLETION RECORD 2' HSD POWER JET V 5 INCH G R 1 CCL CORRELATION FLUID LEVEL DETERMINATION ./ 5 INCH GR 1 CCL CORRELATION FLUID LEVEL DETERMINATION ./ 5 INCH COMPLETION RECORD 2' PJ HSD, 6 SPF V 5 INCH COMPLETION RECORD 2' PJ HSD, 6 SPF V' 5 INCH COMPLETION RECORD 2' PJ HSD. 6 SPF V 5 INCH COMPLETION RECORD 2' PJ HSD, 6 SPF V 5 INCH GR/CCLI PRESSURE 1 TEMPERATURE ITOP OF FLUID DETERMINATION V 5 INCH GR 1 CCL 1 PRESSURE 1 TEMPERATURE 1 TOP OF FLUID DETERMINATION v 5 INCH OR 1 CCL 1 TEMPERATURE 1 PRESSURE 1 TOP OF FLUID. SAMPLE ¡/" 5 INCH GR 1 CCL 1 TEMPERATURE 1 PRESSURE 1 TOP OF FLUID, SAMPLE ~ 5 INCH GR 1 CCL TEMPERATURE, PRESSURE TOP OF FLUID, SAMPLE V 5 INCH GR 1 CCL TEMPERATURE, PRESSURE TOP OF FLUID. SAMPLE"/ 5 INCH COMPLETION RECORD 111/16' POWER PIVOT ./ 5 INCH COMPLETION RECORD 111/16' POWER PIVOT v 5 INCH COMPLETION RECORD POSISET PLUG 20' CEMENT PLUG ,/ 5 INCH CEMENT RETAINER CPST SETTING TOOL ,/ 5 INCH MD FIELD PRINT" 2/5 INCH I~EUTRON 1 GR 1 CCL ./ 2/5 INCH I~EUTRON 1 GR 1 CCL V 2/5 INCH 6.5' THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG,/ 5 INCH 5.5' THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG v51NCH 2' HSD POWER JET 6 SPF COMPLETION RECORD ........ 5 INCH ~ 6/21/2002 6/27/2002 6/27/2002 6/27/2002 2/812002 2/812002 7115/2002 7/15/2002 10/31/1999 10/31/1999 4/312002 4/3/2002 4/2/2002 4/2/2002 3/29/2002 3/29/2002 3/29/2002 3/29/2002 3/28/2002 3/28/2002 3/29/2002 3/29/2002 3/29/2002 3/29/2002 5/16/2002 5/16/2002 3/13/2002 6/27/2002 6/29/2002 6/26/2002 6/26/2002 13100-13696 13150-13670 13150-13670 13150-13670 9544-12045 9544-12045 5300-5975 5300-5975 1473-6430 1473-6430 8600-9750 8600-9750 8600-9790 8600-9790 5420-6066 3690-4250 5420-6066 3690-4250 3550-6954 3550-6954 3550-6607 3550-6607 100-6948 100-6948 5400-5600 5400-5600 4600-5642 5600-6346 6044-6912 5600-6340 5600-6340 8/20/2002 6025-6050 8/20/2002 6025-6050 8/4/2002 3800-4000 7/24/2002 1987-4105 7/24/2002 1987-4105 8/1/2002 0-4014 8/1/2002 0-4014 7/24/2002 1987-4105 7/18/2002 1952-4105 7/18/2002 1952-4105 5/19/2002 10350-10625 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Film B-Line CD Film B-Line Film B-Line Film B-Line Vellum B-Line Film B-Line Film B-Line B-Line Film Film B-Line Film B-Line Film B-Line Film B-Line Film B-Line B-Line B-Line B-Line CD ARRAY INDUCTION 1 DENSITY 1 CNL/GRISP 1 CALIPER 1 PEX " 5 INCH B-Line CD B-Line B-Line CD B-Line CD B-Line 2 B-Line 2 B-Line 1 B-Line Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. p~~r"'~;\n:. RE>,ceived By ~ '- '/. n/7/'o / Date'. ¡¡ \k .,,¿:~~ Vi ¡¡."., C/-~_l~~ OCT 0 :_:1 ARRAY INDUCTION 1 DENSITY ICNL/GRI SP 1 CALIPER 1 PEX .,/ 5 INCH CEMENT BOND LOG/GR/CCL ........ 5 INCH CEMENTBONDLOG/GR/CCL 5 INCH v COMPENSATED NEUTRON LOG IN CASING v' 5 INCH SLiMPULSE 1 GR 1 MD 1 FIELD PRINT ,/ SLiMPULSE 1 GR 1 VD 1 FIELD PRINT ./ 111/16 ENERJET GUN COMPLETION REPORT V 2/5 INCH 2/5 INCH 5 INCH Aias¡.;a: <.:< vDmmi8Sion Anchcf8[1o STATE OF ALASKA ALASKA OIt..,AND GAS CONSERVATION <.. v1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .~ ,,---' 1, Status of Well Classification of Service Well OIL: GAS: X' 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519-6247 4. Location of well at surface f ~ 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK .' COMPLËTlOffl DATE, At Top Producing Interval . ~ . 11.o!-. ! 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK r VeR~ß) . At Total Depth ~. ,fiP; .~ 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK . '-_I. . 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 17.37' RKB Private 12. Date Spudded 13. Date T.D. Reached 114. Date co~, Susp. or Aband. 115. Water Depth, if offshore 116. No. of comPletj' ns 2/17/02 3ßafõ2)j) ~1.II:pon~J...sb feetMSL ~ SIJSrct~Dt::U ~ 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 8000' MD Yes: No: X feet MD 22. Type Electric or Other Logs Run SUSPENDED:&: J-b ABANDONED: SERVICE: ".",""+¡.'., , .~....j", ~lv::A~* '. '. ~ r 1(: . ~ ~\ 7. Permit Number 202-011 8. API Number 50- 133-20509-00 9. Unit or Lease Name Pearl #1 10. Well Number No.1 11. Field and Pool South Ninilchik Prospect 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE wr. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD 13-3/8" 61# K-55 Surface 91' DRIVEN DRIVEN 9-5/8" 47# L-80 Surface 1791' 12-1/4" 230 SX 7" 26# L-80 Surface 4983' 8-1/2" 814 SX AMOUNT PULLED 0 0 0 SEE ATTACHED SCHEMATIC TUBING RECORD SIZE DEPTH SET (MD) 3-1/2" 3788' 3/8" 1968' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PACKER SET (MD) 3706' 24. Perforations opHn to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. 7798'-7836' WIL Test 7289'-7319' WIL Test 5694'-5734' W/L Test 4008'-4043' W/L Test PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-Oil RATIO TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBl GAS-MCF WATER-BBl OIL GRAVITY-API (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 27. Date First Production Date otTest NIA Hours Tested SEE ATTACHED MUD LOG ORIGINAL RECEIVED JUl 30 2002 AblSkaœa~,~tilS\ !;OfHr11t!:>'SIU' 8firOt'-:,U'1'1: Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBDr.fS BFl Submit in duplicate JUt 3! 2002 .~ tAS/¡f ~f ~ ~ ~- "'-¿LA f fJ/~ ~ ~~ AfNÆ~ ~ ~. STATE OF ALASKA ALASKA OILAND GAS CONSERVATION (,vMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL: GAS: 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519-6247 4. Location of well at surface 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK At Top Producing Interval 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK At Total Depth 1568' FNL, 1968' FWL SEC 24, T01S, R14W, SM AK 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 17.37' RKB Private 12. Date Spudded 13. Dat~)1P' Reached 114. Date Comp-., Susp. or Aband. 115. Wat Depth, if offshore 116. No. of Completions 2/17102 3!gi102 j!J> .4/1'?1~~\~r&'ntod jÞ feet MSL SUSPENDED 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. D th where SSSV set 121. Thickness of Permafrost 8000' MD Yes: No: X feet MD 22. Type Electric or Other Logs Run TUBING RECORD SIZE DEPTH SET (MD) 3-1/2" 3788' 3/8" 1968' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED '.~,/ ~.? / PRODUCTION TEST I fthOd of Operation (Flowing, gas lift, etc.) PRO¡¿ÓCTION FOR OIL-BBL GAS-MCF TESt PERIOD => Flow Tubing Casing Pressure jt'CULATED Press. -HOUR RATE => 28. CORE DATA B,eld""":;E: :::::1:"""'" appereo' dip' cod p'",eooo of on. ." '" wele,- 8obmU oore "'IPR E eEl V E D / JUL 2 4 2002 / 1. Status of Well SUSPENDED: X ABANDONED: SERVICE: 23. CASING, LINER AND CEMEN . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 13-3/8" 61# K-55 Sl,Jrface 71' 9-5/8" 47# L-80 Surface 2140' 7" 26# L-80 Surface 9926' 7" 29# L-80 9800' 118' 24. Perforations open to Production (MD+TVD ofTop and Bottom an interval, size and number) HOLE SIZE DRIVEN 12-1/4" 8-1/2" 8-1/2" 25. SEE ATTACHED SCHEMATIC 7798'-7836' W/L Test 7289'-7319' W/L Test 5694'-5734' W/L Test 4008'-4043' W/L Test 27. Date First Production Date of Test N/A Hours Tested OIL-BBL GAS-MCF ORIGIN¡;L Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE "-"', Classification of Service Well 7. Permit Number 202-011 8. API Number 50- 133-20509-00 9. Unit or Lease Name Pearl #1 10. Well Number No, 1 11. Field and 01 South ilchik Prospect CEMENTING RECORD DRIVEN 230 SX AMOUNT PULLED 0 0 0 0 PACKER SET (MD) 3706' WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (corr) WATER-BBL Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate -, .-- 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS,DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase, RECEIVED JUL 2 4 2002 Alaska Oil & Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS PERFORATION DATA SHEET, ABANDONDED WELL SCHEMATIC, SUMMARY REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~ ðL \ ~~^'- Title Or !\,,~ ~"1JJr Date d J.7 c7J o-el.J:;). INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". FDrm 10-407 U'n ~'.J ! (' I f\l A,v.. L .f\\û\!\l -- 14 13 23 24 D ~ , ~~. ~~ <ç;~ ~<\ / / 1970' FWL ~ NOTES 1) BASIS OF COORDINATES: NGS STATION V82 (ADOT) NAD21 2) BASIS OF ELEvATION: NGS 13M V82 NGVD2~ 3) SECTION LINE OFFSETS DERivED FROM TIES TO SURVEY MONUMENTS ALONG NORTH BOUNDARY OF SECTION 24 TIS RI4W SM FOUND THIS SURVEY APPLICANT: UNOCAL8 909 W. 9th Avenue Anchorage, AK 99519-7685 P.O. 8ox 468 SOLDOTNA, AK 99669 ~ .. ""'\"t ......' OF At.. . t : ~\"""""..1& I, -~~" *""1- " = VJ.: "."7 ~ 5, 'Jj¡I!ip ..¡ p p ... *. ~ ~.,..,.U:~.~"...: , ~ '..M. SCOTT MCLANE.:' ff ... I ,.. '. . ~- I \1'-" ". 4928-5 ..'.§:"- 'i ~<'()~O/J,~/.D.r~-fJ".?' It. ~O¡:-E:SSION¡"\. \. ....' a,\\\"", ~ ¿ SECTION 24 : TOWNSI-iIF 1 SOUTI-i IS) RANGE 14 WEST I%J SEWARD MERIDIANlt ALASKA 1< /::( dk Ii-:. IQ l'f IlL¡ I): 10( l.'f /0 -.J Z Z~ 0 r--- Lí) 1 I 1 . FROFOSED ~ # WELL 0.. FEARL NO.1 E SURFACE ::/ LOCATION !f ASP ZONE 4 NAD27 1 GRID N: 2224511.630 I GRID E: 205854.039 I LATITUDE: 60'04'45.670" / LONGITUDE: 151 '36' 38.877" ELEV.: 222.5 FT. NGVD29 Sheet 1 of 1 PEARL NO.1 SURFACE LOCATION I Date: 10/19/01 SCALE 1 inch = 200 it. 0 200 r-..V FIGURE: 1 400 I ConsuLting ~ roup Testing OFFSETS 1970' FWL SECTION 24 1570' FNL T1S R14W SM AK TEL 907.283.4218 FAX 907.283.3265 Dwg: pearll 300 , -- --- South Kenai Gas Project Pearl # 1 Well Daily Summary Unocal Alaska Drilling Daily Summary Report I Pear/# 1 Grassroots Exploration Well 2/12/02 to 04/02102 2/12/02 Accepted rig from well NNA-1 at 18:00 hrs, 02-12-02. Prepared rig 1 equip for Moved to Pearl # 1. Prepped derrick for layover. Removed v-doors and wind walls. RID flow line. Removed degasser stacks and stairs to pits. Hinged up monkey board fingers. Laid over beaver slide. Disconnected Tesco unit (conex) and catwalk from sub-base. Spotted drilling line spool. RID poor boy degasser line. PJSM. Laid over derrick. Removed derrick board and wind walls for same. 2/13102 Hung off blocks. Slipped & cut 70' of drilling line - spooled off remainder. Prepared pits for moving (removed lights, pulled equalizer lines between pits, broke loose mud broke troughs from ice and removed). Removed winterizing from rig floor and cellar entry. Broke apart service lines. Tied up lines in derrick. Prepared pump house and sub-structure to move. Removed remaining derrick lines in prep for splitting derrick. Rigged down berms. Pulled out boiler. (Pits ready to Moved). Loaded and moved choke house 1 cat walk to staging area. Loaded and moved conex, boiler house and suction pit. Set ramps and laid over "A" legs. Disconnected phone lines and power to camp. (Moved satellite dish to Pearl # 1). Loaded out and moved company 1 pusher trailer to Pearl # "1. Loaded draw works skid. Loaded Pump # 2. (2 rig mechanics working on Unocal Gen set to power camp trailers). Moved legal (Delayed starting to layout felt 1 liner on Pearl # 1 due to high winds). Loaded out and moved doghouse and water tank (below doghouse). Removed derrick from substructure. Readied derrick for splitting. Readied substructure to load 1 Moved. Removed derrick shoes. Loaded and moved suction pit. Removed and loaded out crown section. Shut down moving wide loads from 2:30 to 4:15 - school busses. Loaded up and prep to moved substructure and butt section of derrick. Loaded and Moved 5 sections on rig mats. Laid felt and liner (holding in place with rig mats) on Pearl # 1. Set rig mats in place. Installed derrick shoes on substructure. 2/14/02 Rigged up on Pearl # 1. Set Matting boards. Folded out wing floor section on substructure. Set derrick feet. Tied onto sub and aligned over hole. Shut down rig up. Held spud meeting. (Road trucks moving wide loads from NNA#1). Spotted sub on well. Set water tank, raised doghouse, set draw works, set #1 & #2 pump skids, gen-set, shaker tank and suction tank. Spotted mast sections and Mlu. RlU string up line. Set mast on sub and pin same. Set mast on derrick stand. Raised '~" legs and pin same. Set Boiler and "shop" conex. Strung blocks and worked on service lines. ~ ,~, 2/15/02 Tightened drill line anchor. Put tension on drilling line. Unsecured blocks. Hung monkey board on derrick. Ran electric cables to derrick. Shoveled snow from cable trays. Rig up pits, stairs, tarps and plumbing. Prepped to raise derrick. Raised derrick and pin. Installed diverter knife valve. Rig up wind wall scaffolding. Hooked up accumulator remote and hydraulic remote from rig floor. Hooked up mud lines in pump room. Moved derrick stand. RIU Geronimo line. RIU scaffold on floor. Folded over roof caps. RIU all hoists. RIU bell nipple. Spot catwalk. Folded over tool-slide. Installed canvas walls on floor. RIU gas buster. Started filling boiler tank with water. Aired up all boots in pits. Unbridled and secured bridle lines. Shoveled snow from rig. P/U tools. Secured "poor boy" de-gasser. N/U flow line. Set de-gasser vents. RIU steam lines. Rotated knife valve N/U diverter line. Off loaded trucks. RIU hose from water well. Started filling rig tank and pits. Ran Koomey lines. R/U climber, tongs, weight indicator, and V-door wind wall. Installed mouse hole and flow-line jets. Built containment berm at end of diverter line. Began changing pump liners to 6". Function tested diverter - ok. Set service bldgs. Continued to modify mud system for OBM, i.e. Cuttings dumps and flow line tie ins. 2/16/02 Set cuttings tanks, mat for diamond tanks, shock tank, and OBM pre-mix unit. , Continued setting service bldgs. Set Vac system power unit. Offloaded Tesco hose reel and power unit. Spotted reel and unit inside containment. Set Top , drive rails on walk. PJSM. Rigged up to hang rails in derrick with blocks. Installed TDS torque rails in derrick. Continued berming around rig. PJSM. Rig up "T" bar to torque tube above "A" legs. Adjusted and torqued up same. Hung torque tube off crown. (Continued setting OBM tanks 1 equip. Continued berming around rig and equip.) Rigged up turnbuckle clamps to derrick braces . and torqued up. (Began building truck ramp onto reserve pit) R 1 U saddle on . hose reel hoist and secure at derrick board. PI U Torque tube drive bushing. , (Continued welding on rig 1 equip in preparation for OBM. Welded and set splash guards on shakers, Constructed centrifuge and desander chutes to cuttings tank, Welded up cemented dump line, installed brackets for vac system). Continued setting OBM equip and berming around rig 1 equip. Continued constructing truck ramp for reserve pit. Constructed forklift ramp for access to hopper house with mud material. P 1 U TDS. P / U rail guide. M / U TDS service lines. (Prepped to mix spud mud. Leaking suction valve in pit # 3 - repair) M / U Kelly hose to derrick goose neck. (Set spill containment conex. Continue berming). Installed saver sub. Adjusted torque tube. R / U boot on service lines, bails, and strap on service line saddle. Attempted to adjust 1 turn Kelly hose - rubbing / ridding along dead line and catching on dead line guide - unsuccessful. Performed diverter test as witnessed by Jeff Jones of the AOGCC. (PVT functions - flow show, gain, loss. Gas detection system -alarm horn not working). Set mouse hole. Measured for welder. L / D mouse hole and weld same to seal up. Attempted to adjust Kelly hose. Welded anti-skid tabs on pipe rack "gator tail covers. Slipped drill line excess wraps back to spool. Finished installing cuttings chutes on centrifuge and de-sander. (Mix spud mud) 2/17/02 Re-installed drilling line on dead-man and secured same. Installed dead line sensors. P 1 U blocks and removed bridle line. Installed mouse hole. Placed drilling line spool on matting boards. Spotted pipe racks. Removed "V" door to /~ ~ prevent injuries due to high winds blowing straight into "V" door. RID hydraulic lines to drill line spooling unit and re-rig lines to pipe spinner. Strapped 4" drill pipe. Installed shaker screens (84's on one - 110's on the other). RlU to P/U 4" DP. Adjusted crown-Q-matic while off loading 4" DP and strap same. P / U 1500' of 4" DP (drift to 2") and stood back in derrick (Rabbit hanging up - having to free. Having to steam jts at times). P / U 12 1/4" BHA (stabilizers) and steam off while off loading 4" HWDP P / U 4" HWDP ( drift to 2" ), X / 0, Combo Jars and stood back in derrick. P / U 8" DC's and stood back in derrick. M / U 12 1/4" cone bit on I st stand and stood back. P / U Cameron 9 5/8" hanger with 9 5/8" pup JT below and 9 5/8" landing JT above. Landed 9 5/8" hanger in wellhead and marked landing Jt (21.31') RKB. RIH with 12 1/4" bit. Broke Circulation and checked pits / pumps. Pressure tested pumps to 800 psi - ok. Tag soft fill at 93' RKB. Washed to 112' RKB (firm). P / U to 104'. Broke connection. Ran survey - 3/4°. Hooked up Epoch. M / U Stand. Spudded Pearl # 1 at 18:00 hrs 2 /17 / 02. Drilled 12 1/4" hole F/112' to 265' p, (to bury BHA) at reduced flow rate (75 SPM - 240 GPM to 120 SPM - 385 GPM). POOH and stand back DP. M / U BHA and RIH with remaining 8" DC's and top stabilizer. Continued drilling 12 1/4" hole from 265' to 555'. Continued increasing pumps from 385 GPM to +/- 745 GPM. (sucking cuttings from "cuttings tank" and dumping into reserve pit with "Super Sucker" truck) 2/18/02 Continued drilling 12 1/4" hole from 555' to 1800' MD. Pumping at +/- 770 GPM- pump press 1300 psi increasing to 2400 psi. WOB 5 K increasing to +/- 22 K. ROP ranging from 60 FPH - 250 FPH (ave +/- 100 FPH) Mud wt - 9.1 PPG to 9.2+ PPG. Vis - 80. (Sucking cuttings from "cuttings tank" and dumping into reserve pit with "Super sucker" truck). Pumped 50 bbl Hi-vis sweep and circulated to surface. Had med Increase in amt of cuttings across shakers. (Large amt of "clay" balls). POOH with 5K to 10K drag (various tight spots ranging from 25K to 40K drag - worked to clean up). IBS's were balled up. Monitored well - .8 BPH loss. RIH with no excess drag to 1714'. Tagged up - would not "work" through. M / U TDS. Washed / reamed from 1714' to 1800' - ok. (Worked "tight" spot several times - ok.) Pumped 50 bbl Hi-Vis / LCM sweep, circulated to surface. Had med/large increase in amt of cuttings across shakers. with large amt of large clay balls. (Sweep was +/- 50 bbls late = +/- 20% washout). Dropped survey. (Spotted and rigged up Schlumberger logging unit - while circulating and POOH). BGG - 3 units. POOH with +/- 6K drag max. Recovered inclination survey (112 O). Laid down stabilizers, pony collar and bit. Cleaned floor. PJSM. RlU Schlumberger equipment. 2/19102 PJSM. RIH 70' to warm up Schlumberger tools. POOH installed source. RIH to . 1792'(WLM). Logged from TO to surface wI PEX-AIT. RID Schlumberger equipment. Download Schlumberger computer and Moved unit. (mud loss - +1- 1 BPH). Removed stabilizers and bit breaker from catwalk. RID elevators, bails. PIU 11' bails. PIU GBR equipment. Spotted power unit inside containment berm. C/O rig tongs for casing back-up tongs. (Could not spot power unit earlier due to 9 518 " csg or Sehlumberger Unit I diverter line in the way). PI U and M I U 9 5/8" shoe track (Weatherford 9 518" Guide shoe, 2 Jt 9 518", 47#, L-80 New csg, Weatherford. Float collar - 85.20'). Filled esg. Checked floats - ok. Continued P / U and RIH with a total of 40 Jts (1752') of 9 . 518" 47#, L-80 BTC and Mod BTC New esg. (8 jts of Mod BTC ran) with no excess drag. P I U and M I U cameron 11" X 5M fluted hanger (with pup jt . --.., '-. below - landing jt above). Continued RIH and landed hanger in wellhead (correct position) with no excess drag. Slacked off - ok. Removed elevators and prepped to P / U cmt'ing head. 9 5/8" csg (with 13 3/8" Conductor / wellhead and diverter) started moving down hole. Put on elevators and P / U on 9 5/8" csg. 13 3/8" conductor / wellhead and diverter had moved down 8 3/4". R / U to P / U 133/8" conductor / wellhead / diverter with 1" sling (through bails) while picking up 9 5/8" csg with elevators. P / U 13 3/8" conductor / wellhead / diverter and 9 5/8" csg +/- 9" (165 K Max hook load). (When conductor / wellhead fell - Hydraulic lines on hydril were damaged. Chains on turnbuckles were broken). Rigged up circulating swage on 9 5/8" csg. Broke circulation and circulated at 55 SPM - 100 psi. (talked to office). Repaired hydraulic lines on hydril and turnbuckles). Shut down pumping/ circulating. N / D flow line and bell nipple. R / U rigs BOP lift rams / slings onto hydril. Slacked off slings going through bails while continuing to hold 9 5/8" csg load in elevators. Broke circulation and circulated down 9 5/8" csg taking returns to the cellar. Sucked out returns mud returns in cellar and transferred back to shakers. P / U and worked 9 5/8" csg while circulating - ok. Built up split slip bowl +/- 6" from rotary table. landed 9 5/8" fluted hanger in wellhead and set down +/- 2 K. Stopped pumping / circulating. Verified hanger landed (marks / measurements). Set slips on 9 5/8" csg in built up split slip bowl. Removed elevators. R / U Dowell cmt'ing head. Broke circulation with rig pumps. Circulated mud returns to cellar, sucking mud returns from cellar with vac trucks and off loading across shakers. R / D 9 5/8" elevators. R / U 1" sling through bails and attached to shackles on hydril. P / U 20 K on sling (picking up on 13 3/8" conductor / wellhead / diverter to seat into 9 5/8" hanger). Circulated to condition mud (YP-12) and prepped to cmt. Shut down circulating. Emptied vac trucks. PJSM. Tested cement lines to 3000 psi. Dropped bottom plug. Pumped 30 bbl mud push with marker dye using rig pumps. Mixed and pumped 106 bbl (302 six) class "G"12.8# lead cement as per program. Mixed and pumped 48 bbl. (230sx) class "G"15.8# tail cmt as per program (50% excess). Dropped top plug. Began displacement w/ Dowell pumps @ +/-5 bpm. 2/20/02 Continued displacing cmt with 9.3 PPG WBM with Dowell. With +/- 49 bbls displaced (total displacement - 128 bbl) observed mud push at surface (30 bbls of mud push pumped with red dye marker). With +/- 80 bbls displacement pumped observed cmt returns to surface. At 122 bbls displacement pumped lost all returns. Bumped plug at 128 bbls displacement pumped (calc'ed displacement 125.3 bbls). Displaced at 5 BPM - 750 psi Max press. Slowed rate to 2 BPM - +/- 600 psi. Bumped plug to 1100 psi - ok. Released press - floats holding. Circulated +/- 42 bbls of 12.5 PPG cmt to surface. CIP at 00:20 hrs 2 / 20 / 02. (While displacing)- took returns out 4" csg valves into cellar and transferred mud to shaker by Vac truck. With mud push to surface started transferring mud push and cmt to South end of reserve pit by Vac truck). (Note: took Dowell 32 min to mix and pump 48 bbls of tail cmt). Washed up cement unit and blew down lines (discharged to cellar and transferred to South end of reserve pit by Vac truck). R / D Dowell equip. Vac / cleaned cellar for welders. R / D 12 "diverter line / knife valve and mouse hole (to allow installation of base plate). See note in general comments below. While woe - Set base plate in cellar and trim to fit. Pre-heated 13 3/8" conductor. Welded base plate and gussets to 13 3/8" conductor. (Removed equip from catwalk, cleaned mud pit # ,-~ ,,-- 1. Hooked up new gas buster pipe to possum belly. Hard lined gas buster to choke line and mated up to choke house. Changed out driller's side Hyd winch line). Welder finished installation of base plate a 12:00 hrs. Held PJSM. Wt indicator load - 48 K. Slacked off rig rams / tensioned lines - no change on wt indicator or movement on diverter / 13 3/8" conductor. Slacked off slings attached to hydril. Wt indicator to 28K (20k loss). No Movement on diverter / 13 3/8" conductor. Latched elevators onto 9 5/8" landing jt. P / U to 98K (9 5/8" up wt of 98K when RIH - on bottom). Removed blocks under split slip bowl (to removed 9 5/8" slip). Removed 9 5/8" slips. Slowly slacked off 9 5/8" csg transferring csg wt to Cameron fluted hanger / wellhead while observing diverter / 13 3/8" conductor and 9 5/8" csg for Movement. With 9 5/8" csg total wt transfer to hanger / wellhead - diverter / 13 3/8" conductor and 9 5/8" csg Moved down 1/ 4" each. Observed diverter / 13 3/8" conductor for movement - none. Backed out 9 5/8" Indg Jt. P / U and M / U Cameron pack-off. Set pack- off and visually verified 9 5/8 pack-off set through hold down port. Ran in lock downs. LID R&R tool. R / D Koomey lines. Nippled down diverter system. R / D Beaver slide, catwalk and choke house and Moved out. N / U Cameron MBS-L 3M "B" section. Injected plastic packing on R-2 seal. R / U and tested between seals to 3000 psi for 15 min. Measure for RKB's. 7" = 19.45'. 3 1/2" = 17.37'. Stacked up BOP's and began bolting up. 2/21/02 Spread Herculite. Spotted catwalk, choke house and Folded over beaver slide. Finished dressing #1 pump w/ 5" liners. Hammered up bolts on sgl gate, mud cross and spool. R / U kill line, HCR, choke line, gas buster line and accumulator control line. Mixed KCL for OBM make up. Filled water tank. Dressed #2 mud pump with 5" liners. Moved trailers and equip to make better use of location space. Organized mud products, diamond tanks etc. Installed master bushings R / D check valve and reconnect line. Installed master bushing. P / U test Jt and test plug. Set pipe racks and started loading 4" DP onto racks. M / U test plug and set (difficulty setting test plug - had to pressure up and pump test plug down in stages). Circulated fluid against bag, through choke to gas buster possum belly (recovered icy sludge - circulated with warm fluid). Set up to test BOPE. Tested BOPE as witness by Lou Grimaldi of the AOGCC. (Tested Hydril, HCR valve and outside kill line valve to 250 / 3000 psi - ok). Tested top (4" DP) rams, inside kill line valve and inside manual valve to 250/3000 psi. Tested bottom (variable) rams to 250 / 3000 psi. Tested choke maniFolded (18 valves) to 250 / 3000 psi. Tested TDS Kelly valve and floor valve to 250 / 3000 psi. Tested blind rams to 250 / 3000 psi. Performed Koomey test - ok. Pulled test plug. Installed wear bushing. R / D test equip. N / D bell nipple. Nippled up flow line / bell nipple. Connected turn buckles to BOP and installed flow line sensor. LID 8" tools from 12 1/4" BHA #1. R/U mouse-hole (hang off for height) and change elevators. R/U to P / U 4" DP. (Set up slide for pipe bundles). P / U 48 joints 4" DP. (Drift w / 2.31" rabbit). Circulated to flush DP. 2/22/02 Circulation. Intended to only flush pipe, however clay/ice balls at surface. Circulated till returns clean. Checked all valves and trip tank for plugging. Blew down TD. POH stand back pipe and strap same. Re-rig to P / U remainder 4" pipe. P / U 48 jts 4" pipe. (drift W / 2.31" rabbit) Circulated to flush pipe. Blew down TD. POH W / 4 " DP stand back and strap. Re-rigged mouse hole for normal ops. P / U Anadril CDR tool (resistivity) and broke off --.., --- X/O to use on power pulse tool. Calibrated Anadril computer to draw works. P / U and M / U 8 1/2" BHA ( with Hughes PDC bit, Anadril 6 3/4" motor, Stabilizer, Anadril MWD w/GR, Stabilizer, 6 1/2" shock sub, 6 1/2" DC, Stabilizer, 4 - 6 1/2" DC's, I Jt 5" HWDP, 6 1/2" combo Jars). Oriented / set motor to .78° (Surface test motor / MWD - ok). Serviced rig / crown / draw works while tightening bolts on TDS and torque rail clamps. Bridled line loose in derrick. Tied down clamp / bridle. Retied bridle line. Continued RIH with 8 1/2" BHA. M / U TDS and took survey at 405' - .86°, 869' - .84° and 1428' - .46°. Pressure tested 9 5/8" csg to 2500 psi - ok. Continued washing to float collar at 1704.5' (no cmt on top of F. C.). Drilled float collar, 85' of very soft cmt, guided shoe to 1791'. Cleaned out "rat hole" and drilled new formation from 1800' to 1820'. (Note: When cleaning out shoe track - circulated very heavy / clabbered mud / cmt to surface. Had to circulate/work pipe until cleaned up). Circulated / work pipe while conditioning mud. P / U inside 9 5/8" csg. Closed Hydril. Performed F.I.T with 9.0 PPG WBM. 9 5/8" shoe at 1791' MD / TVD. Max surface pressure - 325 psi. that equals 12.5 E.M.W. Bled off pressure. Opened hydril. Drilled 8 1/2" hole from 1820' to 2328'. ROP ranging from 70 FPH to 190 FPH. Pumped at +/- 575 GPM with +/- 1250 psi pump pressure. WeB ranging from 4K to 8K. Max gas - 172 Units at 1986'. BGG +/- 40 units. Mud wt gradually increased from 9.0 PPG to 9.4 PPG 2/23/02 Continued drilling from 2328' MD to 2782' MD. ROP ranged from 40 FPH to 167 FPH. WeB ranged from 7K to 12K. Pumped at +/- 575 GPM. (Reduced mud wt from 9.4+ to 9.2+). Max gas 207 Units at 2530', BGG - +/- 45 units. Circulated bottoms up while working pipe. Surveyed (1.25°). POOH from 2782' to 2550' with +/- 30K drag at times (worked through tight areas - cleaned up). At 2550' drag increased to +/- 40K and would not clean up. Attempted to swab. RIH to 2590'. M / U TDS. Back reamed from 2590' to 1840' pumping at +/- 50 SPM. Experienced high drag and attempted pack off several times. Worked through areas - cleaned up. Worked pipe from +/- 1950 to 1840' while circulating bottoms up. No increase in amt of cuttings. Shut down pumps. Continued POOH to inside 9 5/8" shoe. Greased swivel packing and blocks. Checked oil in TDS. RIH to 2695' with no excess drag. M / U TDS. Washed to 2782' - ok. (Trip gas - 82 units). Drilled 8 1/2" hole from 2782' to 2878' with ROP ranging from 40 FPH to 90FPH with 8K to 12K WeB. Surveyed - 1.35°. Oriented high side and drilled (sliding) 18' from 2878' to 2896' at ROP ranging from 5 FPH to 40 FPH with +/- 7K WeB. Rotary drilled 8 1/2" hole from 2896' to 2972' with 1 OK to 12K WeB. ROP ranging from 80 FPH to 105 FPH. Surveyed - 0.87°. Continued rotary drilling 8 1/2" hole from 2972' to 3066' at 80 FPH to 100 FPH ROP. (TDS stopped rotating - unit shut down +/- 10 min. # 1 pump oiler broke. Circulated / drilled with # 2 pump for +/- 15 min until repaired). Surveyed - 0.78°. Continued drilling 8 1/2" hole from 3066' to 3156'. ROP 80 FPH to 105 FPH with 8K to 1 OK WeB. Surveyed - 0.87°. Directionally drilled (sliding) from 3156' to 3178' (22') at 25 FPH to 35 FPH ROP. Continued rotary drilling from 3178' to 3249' at 80 FPH to 120 FPH ROP. Surveyed - .34°. Directionally drilled (sliding) from 3249' to 3259' (10') at 30 FPH to 40FPH ROP with +/- 7K WeB. Continued rotary drilling from 3259' to 3540' @ 90 to 130 FPH with 8K to 11 K WeB. Max gas (coal) 461 units @ 3103' BGG 35/25 2/24/02 Continued rotary drilling 8 1/2" hole from 3,540' to 3,809' @ 95 /135 FPH with 5- 12 K WeB max gas (coal) 463 units at 3,623'. Circulated (bottoms up) while .---- ,~ working drill pipe. Surveyed - .35°. POOH from 3809' to 3620' with +/- 25K max drag. At 3620' well attempted to swab with +/- 25K drag - would not clean up. M / U TDS and began back reaming from 3620'. Back reamed from 3620' to 2214' with +/- 10K drag (20K to 30K at times with torque increasing and attempting to pack-off, cleaned up - ok). POOH from 2214 to 2024' with 10K to 15K drag (at times). RIH from 2024' to 3714' with no excess drag. M / U TDS. Broke circulation. Washed from 3,719' to 3,809' ok. Drilled 8 1/2" hole from 3,809' to 4,833' Max angle 0.55°. WeB 10 to 15K. ROP - 85 FPH to 200 FPH. Pumping at 625 GPM at +/- 1900 psi increasing to +/- 2300 psi. 2/25/02 Drilled 8 1/2" hole from 4,833' to 5,068 WOB - 10K to 12 K. ROP - 65FPH to 140 FPH. Sand from 5,030' to 5,068'. Worked pipe and circulated bottoms up. POOH (short trip) from 5068' to 4840' - attempted to swab. Pumped out of hole from 4840' to 4502' -ok. At 4502 drag increased to +/- 25K. Back reamed from 3502' to 4400'. Pumped out of hole from 4400' to 4360' - drag increased to +/- 30k (attempted to swab). Back reamed from 4360' to 3742'. Attempted to POOH - well attempted to swab. Pumped (no rotation) from 3742' to 1963' with +/- 5K to 10K (at times) drag. POOH from 1963' to 1800'. Service rig (blocks, swivel, etc) while changing dies on TDS gripper. Monitored well. Nippled down (take loose) flow line. R / D (take loose) bell nipple and link bell nipple / flowed uþ together. Installed (split) bell nipple spacer spool (to place lip up against rotary table). Lowered bell nipple / flow line and nippled up. Transferred 30 BBL CaCI spacer to pre-mix system. Transferred +/- 100 bbls "Monopod" 9.3 ppg OBM to # 6 pit and weight up to 10 ppg - Heated "Monopod "OBM before transferring. Transferred WBM from # 5 and # 4 and began cleaning pit # 5 and # 4. Cleaned Pit # 1). P / U (rabbit with 2.3" rabbit) 24 jts of 4" HT-38 DP. (Continued cleaning pits / shakers, shaker and centrifuge / desander cuttings tanks, rig pit troughs and cellar - transferred WBM fluid to reserve pit). RIH with no excess drag (one" tight spot at 2930' - cleaned up ok). M / U TDS and washed last 50' to bottom at 5068' (taking WBM returns to pit # 3 only) Finished cleaning pits / shakers etc. Suck WBM volume down in pit # 3 and transferred to reserve pit. Transferred 30 bbl 10 PPG spacer to pill pit. Transferred "New "OBM to pits # 4 and # 5. Pumped 30 bbl Flo-Vis spacer mixed at 10 PPG. Pumped (from pit # 6) +/- 100 bbls "Monopod "OBM wt'ed to 10 PPG. Pumped "New "OBM (wt'ed to 10 PPG) from pits # 4 and # 5. Began transferring remaining "New "OBM to pits # 4 and # 5. Displaced WBM to pit # 3 and shale cuttings tank while transferring WBM from pit # 3 and cuttings tank to reserve pit. Observed weighted Flo-Vis spacer at surface and diverted +/- 16 bbls of spacer to pit # 1. After +/- 16 bbls spacer at surface observed very thick / clabbered WBM / OBM / cuttings. Attempted to divert flow down trough - too thick. Dumped +/- 10 bbl very thick / clabbered mud to cuttings tank. (Shaker cuttings tank had been sucked down (WBM) to +/- 5 bbls remaining). Diverted thick mud down troughs (shoveling to Moved down trough - # 84 screens blinded off - reduced pumping to 40 spm). Continued circulating with mud gradually thinning. Gradually increased pump strokes to 120. Began cleaning # 3 and # 2 pits. Discharge hose on # 1 pump leaking. Shut down # 1 pump and began changing out / cleaning up. Continued circulating with # 2 pump (working pipe) while cleaning # 3 and # 2 pits. Pits # 3 and # 2 clean. OBM - ok. Drilled 8 1/2" hole from 5068' to 5113' with # 2 pump (circulating at 140 spm - 320 GPM). ROP 100 FPH to 150 FPH. Pump # 2 back on line. Drilled 8 1/2" -- ",-.. , hole from 5113' to 5389' with 180 spm - 420 GPM, 140 RPM, WOB 8K to 12K, ROP 80 FPH to 200+ FPH rate. 2/26/02 Continued drilling 8 1/2" hole from 5,389' to 6137' WOB 6K to 12 K. RPM 140. 420 GPM. Simulated a connection (SIT) then circulated bottoms up for wiper trip. POH from 6,137' to 4,144.' P / U 42 joints pre-rabbited 4" DP and RIH (Can drill to 1447'). Drill-rotate from 6,137' to 6,181'. Drill-slide from 6,181' to 6,181, drill-rotate from 6,187' to 6,203', drill-slide from 6,203 to 6,204' (slide footage 1 hour total) 2/21/02 Drill rotating from 6,204' to 6,232', drill-slide from 6,232' to 6,237', drill-rotate from 6,237' to 6,266', drill-slide from 6,266' to 6,211', drill-rotate from 6,211' to 6,287', drill-slide from 6,287' to 6,303', drill-rotate from 6,303' to 6,628'MD. ROP 35 FPH to 85 FPH. WOB 8K to 12k. Actual slide time was .92 hrs. Rotating was 1.12 hrs. POOH to 6415' to replace the top drive IBOP actuator assembly. Replaced the top drive IBOP actuator and saver sub. Ran back in the hole to 6628', hole in very good condition. Rotary drilling from 6628' to 6912'. Actual rotating time was 1.58 hrs. Avg. ROP = 31.41 fph. 2/28/02 Rotary drilling 8-1/2" hole from 6912' to 1225'. Actual rotating time 9.5 hrs. Ran . extremely low on fuel lost generators; replumbed fuel lines to the boiler fuel tank while waiting on fuel truck. Picked up 60' off bottom and worked the pipe while waiting on fuel, no problems with the hole. Rotary drilling with mud motor from 1225' to 1257'. Core point as picked by Geologist. Actual rotating time 2.0 hrs. Simulated a long connection and circulated bottoms up. No gas or other problems and no mud losses while drilling or circulating. Pumped dry job and POOH to pick up the coring equipment. No drag or tight hole. Stood back BHA. UD Bit #2. Pulled wear bushing, set test plug. Tested IBOP, kill valve, HCR valve and all BOP's to 250/3000 psi. Performed Koomey test - OK. Tested Choke ManiFolded with water and tested the BOP stack with Base Oil. Serviced rig. 3/01/02 Cleaned OBM from floors. PJSM. Picked up core bit and core barrel assy. Made up BHA and ran in the hole to 9 5/8" casing shoe (1800'). Slipped and cut 61' of drilling line. Service TDS. Continued to run in the hole to 1237', had 20' of fill. Washed to bottom hole trying to pack off, a large amount of coal came back over the shakers. Continued to circulate the hole clean had a large amount of hard coal come back over the shakers. Returns cleaned up and hole conditions were good. Broke a joint and dropped the diverter ball and circulated into place. Cored on hard bone from 1257' to 1264'. Cored from 1264' to 1341.5'. Circulated bottoms up. 3/02/02 Finished circulating bottoms up. No increased gas units or cuttings. Pumped dry job. POOH w/ core and coring assy. to 9-5/8" shoe. Observed well - static. Continued POOH w/ core and coring assembly no problems hole in good condition. Laid down inner core barrels, top barrel was de-void of core and full of mud, middle barrel was about 1/2 full and the bottom barrel was full. Cut 84' and recovered about 50'. Laid down the outer barrels, clean the floor and laid down the drilling bottom hole assembly. Made up BHA #4 straight rotary no motor drilling assembly with Bit #2 and ran in the hole picking up 10 stands of rabbitted 4" drill pipe. Had minor tight spots in the bottom section of the hole ~ ,"-"', worked through them without any trouble. Washed and reamed from 7205' to bottom circulated a moderate amount of coal out of the hole. Rotary drilling 8 1/2" hole from 7342' to 7417'. 3/03/02 Rotary drilling 8-1/2" hole from 7417' to 7598'. Rotary drilling 8-1/2" hole from 7598' to 7758'. 3/04/02 Rotary drilling 8-1/2" hole from 7758' to 7808', IBOP started leaking OBM. Top drive IBOP leaking fluid through the operating key, pumped a dry job and pulled 8 stands of drill pipe to 7110'. Had tight spots at 7606', 7518' and 7496' pulled 40 K to work through. Replaced the IBOP valve and actuator. Ran back in the hole to 7808' without any problems. Drilling from 7808' to 7862'. Trouble shot the top drive, unable to rotate at speed and unable to release pipe gripper. laid down 3 joints of drill to get the top drive close to the floor, found the 35 conductor control cable loose, clean connector and fe-tighten. Repaired IBOP actuator control on the top drive. Drilling from 7862' to 7988'. 3/05/02 Rotary drilled 8-1/2" hole from 7988' to 8000'. Circulated bottoms up. Monitored well - OK. Mixed and pumped dry job-:-- POOH to 7110' (short trip). Hole in good shape, no major tight spots. Monitored well - OK. RIH to 7998'. No bridges or fill. Hole appears to be in good condition. Circulated bottoms up, no extra cuttings. Dropped Totco single-shot survey tool. POOH to run open hole logs. No drag or tight hole while pulling out. Set back 4" HWDP & DC's. UD shock sub and stabilizers. Broke off bit. Totco survey was 2 3/4 degree. Rigged up Schlumberger. P/U & M/U Triple Combo tools. PJSM. Loaded sources. RIH and tag bottom. Logged open hole with Triple Combo tool f/ 8000' to 1800'. POOH. UD Triple Combo tools. P/U & M/U CMR logging suite. RIH and tag bottom. Logged open hole with CMR-ECS-GR-DTC logging suite f/ 8000' to 1800'. Laid down logging tools. Waited on Schlumberger's VSP logging tools to arrive from Homer. 3/06/02 Waited on Schlumberger Velocity survey equipment to arrive from Homer. Made up VSP tools, calibrated and ran in the hole and survey. laid down tools and rigged Schlumberger down. Serviced rig and top drive. Ran BHA in the hole and POOH laying down BHA and Jars. Cleared the floor. Pulled the wear bushing and installed 7" casing rams in the top BOP. Picked up the 16' bails, Made up the LeFluer circulating tool, hung the stabbing board rigged up GBR casing tongs. Checked the fluted hanger and drifted it through the stack. Worked on tight hold down bolts. Made up and Checked float equipment and fill up tool. All connections Baker locked to one joint above the landing Collar. Floats worked OK. 3/07/02 Ran 7" 29# l-80 TKC Buttress casing. 120' shoe track with short joints and RA tags at 7009' and 5983' and 4956'. Halliburton ES Cementer - Type H at 5103'. Filled pipe every 2000'. On Jt. #63, guide on block dolly caught stabbing board, bending it. No injuries to personnel or damage to other equipment. Removed and laid down stabbing board. Inspected work area and top drive rail - OK. Laid down LaFleur fill-up tool. Continued running 7" casing. Picked up hanger assembly and landing joint. Landed 7" casing with shoe at 7983', float collar/baffle plate at 7895', landing collar at 7850',20' pup joints w/ RA 'pip' tags at 7010', 5983' and 4956'. Halliburton 'ES Cementer - Type H' at 5103'. M/U -. ,---- ~ Dowell cement head and lines. Loaded bottom plug in cement head. Circulated and conditioned mud. PJSM. Pumped 5 bbls Chem Wash. Tested cementing lines to 3500 psi - OK. Pumped 23 bbls Chem Wash. Dropped bottom plug. Pumped final 2 bbls Chem Wash. Bled off pressure, opened cement head and verified bottom plug had released. Loaded Plug #2. Pumped 30 bbls Mud Push with rig pump. Switch to Dowell pumps and mixed and pumped 560 cu.ft. 15.8 ppg cement slurry at 4.5 to 6 BPM. Stopped pumps, dropped Plug #2, displaced with 5 bbls mix water. Lined up rig pump and displaced cement with 293.8 bbls OBMstarting at 6 BPM, 600 psi and bumped plug at :!:: 2 BPM and 1550 psi. Stage #1 CIP @ 23:32 hrs, 3/7/02. Bled off pressure. Checked floats - floats held OK. Loaded Plug #3. Pressured up on casing and opened ES Cementer' sleeve wI 2900 psi. Circulated through 'ES Cementer' sleeve at 4 BPM, 1200 psi. 3/08/02 Continued circulating out Chem Wash I Mud Push and waiting for 1 st Stage cement to cure. PJSM. Tested cementing lines to 3000 psi. Pumped 30 bbls Chem Wash wI Dowell pumps and 30 bbls Mud. Pushed wI rig pump. Mixed and pumped 393 cu.ft of 15.8 ppg slurry. Average pumping rate = 5 BPM. Maximum pumping pressure = 950 psi. Loaded top plug. Displaced (dropped) top plug wI 5 bbls mix water. Switched to rig pump and displaced plug & cement wI OBM. Bumped plug and closed 'ES Cementer' sleeve wI 192 bbls OBM. Final displacement pressure = 2500 psi. Increased pressure to 3500 psi and held for 5 min. Released pressure, checked for flow - no flow back - floats held. Blow down cement lines. UD cementing equipment and landing joint. Cleaned OBM from tools and equipment. P/U pack off tools. Cleaned stack and RIH wI pack off tools. Secured pack off and tested pack off and neck seals to 5000 psi. UD running tool. Set back HWDP used for weight. Changed to short bails. Adjusted TDS rail. Changed upper rams to 4" and tested same to 3500 psi. Installed wear ring. UD test joint. P/U and M/U cement cleanout BHA #5. Changed out TDS IBOP valve (valve leaking through operating key again). RIH wI cleanout assy. Tagged soft cement at 5034' (took 2-3 Kips weight). Filled pipe. Circulated bottoms up. Tested casing to 3000 psi - OK. Washed & rotated down from 5034' to 5078'. Tagged hard cement at 5078'. Drilled cement, top plug and ES Cementer aluminum seats from 5078' to 5104' wI 12-14 Kips WOB, 50 RPM. 3/09/02 Continued drilling out 'ES Cementer' sleeve from 5104' to 5105'. No problems drilling through the sleeve. RIH and tagged landing collar at 7847' DPM (7850' csg). No cement encountered between ES Cementer and landing collar. Circulated bottoms up. Tested casing to 3000 psi - OK. Continued circulating while transferring 9.6 ppg OBM from pits to storage tanks. Prepared for displacement of OBM in hole to base oil. Displaced OBM in hole wI base oil. Cleaned out trip tank and pill pit. Filled same with base oil. RIU to lay down DP. PJSM. Started POOH laying down DP. Internal pipe wiper not working. Picked DP back up (12 joints) and stood back in derrick to drain. POOH soft breaking each connection then standing back DP. UD BHA. Loaded 3-1/2" tubing onto pipe rack. RIU GBR to run 3-1/2" tubing. Cleaned floor and catwalk. PJSM. Pulled wear ring. P/U and M/U Baker packer assembly. RIH with 3-1/2" tubing to joint #56. P/U and M/U Injection mandrel. Install Pollard 1/4" control line. Pump valve opened and tested control line to 1500 psi. Continued running 3-1/2" tubing and 1/4" control line to joint #102. ,-... ~ 3/10/02 Continued RIH w/ 3-1/2" tubing to joint #117. P/U & M/U tubing hanger assy. Connect 1/4" control line to same. Drained stack and landed tubing hanger. Ran in tie-down screws. Dropped 2-1/8" Kirksite ball and wait 15 minutes for ball to seat. Pressured up on tubing, using test pump, to 2700 psi. Stopped pumping and observed annulus - returns from annulus stopped indicating the packer had set. Continued increasing pressure and ball seat sheared at 3000 psi (expected seat to shear at approx. 3100 psi w/ one pin removed). Pressured to 1500 psi and held for 15 minutes to test the packer and tubing. Cut control line and terminated with a cap. Note: the Control line is 1/4" S.S. laid down the landing joints. Rigged down GBR's power tongs and Pollards Control line running equipment. laid down the 4" drill pipe in the mouse hole. Pipe was clean without any free DBM. Cleaned the rig floor and cleaned the mud stand pipe and top drive lines with warm soapy water. Washed BOP stack out with warm soapy water. Removed turnbuckles from TDS rail. Blew down lines. LID mouse hole. LID top drive. Slipped drilling line. LID top drive rail and load on trailer. LID top drive service loop. 3/11/02 Broke open BOP doors. Washed DBM from ram cavities and closed back up. Nippled down flow line and bell nipple - washed out and wiped down same. Cleaned off each piece from the cellar. Flipped over beaver, slide and moved slide and catwalk out of way. Nippled down stack, kill line, and choke line. Pits cleaned during nipple down process. Nippled up the production tree and tested the void to 5000 psi. Pulled the BPV and installed a TWCV and tested the tree and neck seals to 250/5000 psi. Pulled TWCV and installed a BPV. Continued to clean the pits while working on the tree. Cleaned the mud pits and pumps with steam, hot soapy water and a pressure washer. Cleaned the sub base and cellar area. loaded out Unocal and rental. equipment and shipped to the Griner #1 location. Released the rig to move. to the Griner #1 location.at 24:00 hrs. 03-11-02. WIRE LINE TESTING 3/17/02 MIRU Dowell. Road conditions delayed/slowed equipment delivery to location. RU scaffolding at wellhead, spot crane and equipment. 3/18/02 Installed coiled tubing BOP on top of tree. Continued rigging up coiled tubing equipment. Shut down for remainder of night. Serviced and warmed up coil tubing equipment. Held safety meeting with coil tubing crew. Picked up injector head. Picked up and made up BHA. Function Test BOPE. Tested tree, BOP, choke manifold to 250/5000 psi with fresh water. Loaded coil with fresh water. Tested all rams and pump and lines to 250/5000 psi with fresh water. Blew down coil tubing and production lines with nitrogen. Tested Heater, separator, and surface lines to 1000 psi with nitrogen. Low pressure tested with 130 psi air. Ran in hole to 350'. Blew down coil tubing with N2 to check all valve settings. Ran in hole with 1-3/4" coil tubing to 3780' pumping nitrogen at 450 scfm. Blew tubing dry from 3780' to surface. Ran in hole to 6250' pumping nitrogen at 450 scfm. Lifted fluid to end of tubing. Chased fluid to tubing tail. Blew tubing dry. Ran in hole to 7600'. Lifted fluid to end of tubing. Chased fluid to end of tubing at 3780' pulling slow to removed all fluid. Blew down 3-1/2" tubing. At end of blow down, well seemed to be dry. Strapped ,-.., ~ storage tank, Rec. 110 bbls. Shot 3 fluid levels with coil tubing in well. Showed fluid level at 2740-2760'. Ran in hole with coil tubing to 7600' pumping nitrogen at 800 scfm. Blow down 7" casing from 7600'. Chased fluid up to end of tubing pumping nitrogen at 800 scfm. Pulled slow to removed all fluid. At tubing tail, blew tubing down at 800 scfm. Continued to pull coil tubing to surface pumping at 800 scfm. Shut off nitrogen and trapped 725 psi on well. let nitrogen and foam settle in storage tank. Strapped storage tank, recovered another 34 bbls of fluid. Total recovery now at 144 bbls. Had production shoot another fluid level. Showed fluid at 4500'. Monitored casing with no change. 3/19/02 Rigged down coil tubing injector and shut down coil crew for night. Rigged up Schlumberger to run GR/CCL. Rigged up 5000 psi grease injector. Held safety meeting with wire line crew. Rigged up test unit to test with Methanol. Tested Schlumberger wire line Grease injector to 5000 psi, ok. Ran GR/CCl correlation log from logger's depth 7853' to 3600'. Tied in CCl with open hole log. laid down logging tools and laid down grease injector. Trapped 1000 psi nitrogen pad on well. Held safety meeting with wire line crew" picking up perf. Guns". Picked up Schlumberger's 2" HSD 2006 Power Jet perforating gun loaded 6 spf. Ran in hole and logged perforating guns on depth with CCL. Held safety meeting and job/duties discussion with Schlumberger wire line crew and production crew. Positioned all personnel. Fired guns at 13: 16 hrs. - Had instant slight increase in pressure from 1000 psi to 1025 psi. Perforated 7" casing from 7799' to 7835' with 6 SPF. Pulled out of hole with wire line. - Rigged down grease injector and turned well over to production. Released coil tubing crew and released wire line ërew.- Production ch-ose to hold wire line crew due to possible need to tag fluid after flowing. 3/20/02 left well with 400 psi. Well built to 590 psi overnight! RU Slick line. RIH with blind box and tag fill at 7827' SlM. DiG! not see fluid level with blind box. Pooh. RIH with Sample Bailer and obtain sample of well bore fluid at 7700' SlM. Recovered water. RD Slick line. No indication of combustible gas at surface. Well released to drilling at 15:00 hrs. Accepted well from production at 15:00 hrs 3-20-02. Called out SWS Wire line Crew and Dowell N2 Crew. Waited on Crews to arrive on location. RU SWS E-Line and lubricator w/ 5000 psi grease head. RU production methanol pump to test lubricator and grease head. Filled tree top, CT BOP and Wire line BOP. Made up lubricator to BOP and filled lubricator with methanol using chemical injection pump. Rand K test pump arrived on location at 21 :45 hrs. Need more efficient way of testing lubricators. RU Rand K test pump to test lubricator. PU on lubricator to 2500 psi. Grease head leaking. Bled off methanol. lD lubricator and checked all hoses. PT hoses to 1,000 psi. No leaks. 3/21/02 Broke off top section of lubricator and made up to BOP. Tested grease injector to 2500 psi. Tested ok. Grease injector hoses found to have been air locked. Reassemble lubricator, grease head and tested to 2500 psi OK. Held Safety Meeting with SWS. 750 psi SITP. RIH with GR/CCL/Press/Temp log. Found TOF at 4433'. Continued in hole to Top of Perfs at 7799'. Showed BHP at 2317 psi. BHT 1470 F. POOH with logging tools. Held Safety Meeting with Wire line Crew and N2 Crew. Warmed up engines to pump N2. Pumped N2 pad to well. Pumped 44 scf (473 gallons) of N2 @ 800 scfm pressure tubing from 750 psi to 1850 psi SITP. Shut in well. Re-head rope socket Cut 500' of ~ ~. Wire line and reheaded rope socket. PU SWS's 2-1/8" x 7" 26-36# through Tubing Posiset Plug. Trouble shot and repaired electrical circuits in logging unit to be used to set posiset plug. Opened swab valve and attempted to RIH with Plug. Tool string not heavy enough (130#'s) to RIH - new rubber in PO. PU Lubricator and LD Posiset Plug. PU weight bar for 160#'s. PU Posiset Plug function tested plug OK. RIH with CCL and Posiset Plug to 7799'. Tied in with GRlCCLrremp/Pressure log dated 3-19-02. PU and set Posiset through Tubing Plug with Top of Plug at 7755'. Bottom of Plug is 7' above casing collar at 7766'. POOH with setting tool and LD same. PU 2-1/8" x 36' Cement Dump Bailer. Batch Mixed cement and loaded dump bailer. (3.07' cement/bailer run). Ran SWS Cement Dump Bailer and set cement plug on top of Posiset from 7755'. Made 2 runs with 6.4' of cement in place. 3/22/02 Dumped Bailing cement. Made a total of 8 runs wi 2.125 x 36' Schlumbereger dump bailer @ 3.18' per run Total footage 25.44' from 7755' up to 7729.56'. Rigged down Schlumberger wire line. Waiting on cement. 3/23/02 Waited on cement. @0600 hours had 1600psi on tbg. Dowell CTU crew on location at 11: 15 hrs. Started and warmed up engines on CTU equip. Held Safety mtg. With CTU crew. Re configure return lines at oil tank and water tank to attempt to separate fluids when blowing down well. Installed a 'T' and 2 low torque valves. Tested CTU BOP and production choke manifold WI CTU surface lines' and choke line to 250/5000psi W fresh water, tested ok. Picked up CT BHA. Jet nozzle, X-O sub, straight bar, and coil connector, stabbed injector head. Loaded 14850' of coiled tubing WI fresh water. Tested tree, nitrogen lines, and coil tubing to 250/5000psi WI fresh water all OK. Blew down coil tbg. And all lines with nitrogen to water tank, Bled well press. Down to 550 psi. RIH WI 1.75 coil tbg. To 7700' did not pump nitrogen, final pressure on well 642psi. Opened choke full opened and bled off all pressure, increased nitrogen rate to 800SCF/min had fluid near surface. Nitrogen compressor failed. Repaired broken bracket on compressor. Replaced old comp belts. Function compo Working OK. Resumed pumping nitrogen at 800SCF/min. at 7700'. Pumped for 20 mins, had base oil to surface. Unloaded 40.7 BBLS to oil tank. Continued to pump for a total of 30 mins. At 7700'. Pulled end of coil to 7500'. Had nitrogen return with no fluid. Pumped nitrogen at 800SCFM/min at 7500' for 30 mins. Had base oil to surface. Recovered 14 more BBLS of base oil (54.7 BBLS Total). Started getting water and oil mixture. Switched to water tank and recovered 42 BBLS of water. RIH to 7700' pumping scf/min. Have 30-40 psi on well with nitrogen returns and 400-500psi with fluid returns. Pumped for 30m ins. At 7700'. Pulled back up to 7500' maintaining nitrogen rate at 800scf/min and pumped for 30 mins. With strong nitrogen blow. Pulled up to 4000' with end of coil pumping at 800scf/min while pulling, recovered 15.3 more BBLS of water total recovery now at 112 BBLS. Blew well down for 30 min. @ 4000' @ 800SCF/min. had strong N2 blow with no fluid. Pulled out of hole with coil tbg. Trapped 900psi on well, for N2 pad. Ran out of N2 (back up load in route to well site, will finish N2 pad before logging. Calculated fluid level @ 7447'. Rigged down coil tbg injector. Shot fluid levels, 1st shot 7228', 2nd shot 7495', 3rd shot 6964', 4th shot 6934' 3/24/02 Waited on Schlumberger wire line crew and Nitrogen transport. Have 900 psi Nitrogen pad on well. Will run Gr/CCLrremp/Press log and determine true fluid ,--.", ,....-., level before increasing nitrogen pad. Rigged up Schlumberger wire line unit. Picked up logging tools. Rigged up R&K's test pump. Tested wire line lubricator, wire line BOP, and Tree top to 500/5000 psi. with methanol. All tested ok. Attempted to run in hole with logging tools, Tools would not fall out of lubricator. Laid down lubricator and broke down grease head. Found wire line kinked. Suspect logging tool slid upward inside lubricator when testing to 5000 psi. Reheaded rope socket. Picked up logging tools and picked up lubricator. Rigged up test pump and retested Lubricator, wire line BOP, and tree top to 500/5000 psi, ok. Attempted to run in hole. Wire line rope socket jammed in catcher in top of grease head. Laid down lubricator. Broke down top of grease head. Cleared rope socket catcher. Cleaned and inspected catcher, checked rope socket. All seemed OK. Picked up lubricator and logging tools. Rigged up test pump and tested lubricator, wire line BOP, and tree top with methanol to 500/5000.PSI OK. Opened well (still with 900 psi and no pad) and ran in the hole to approx 2000', wire line shorted out. Pulled out of hole with wire line. Picked up lubricator. Inspected tools, found short in rope socket. Reheaded rope socket. Picked up logging tools and made up lubricator. Ran in hole with GR/CCL/temp/pressure log to 7700'. Temp tool showed fluid level at 7517', 198' below lowest planned perf at 7319'. Ran log from 7700' up to 3600'. Tied in to open hole log. Pulled out of hole with logging tools. Rigged down schlumberger lubricator and secured wire line unit. Rigged up Dowell to pump N2. Pumped remainder of N2 pad to well. Pressured from 900 psi. to 1300 psi. at 1000 scfpm N2. Closed in and secured well. SDFN. 3/25/02 No activity SDFN. Started and warmed up logging Equip. checked out perf. Tools. Held safety meeting and Pre-job Discussion with Schlumberger Wire line crew. Picked up Schlumberger's 2" HSD 2006 power jet perf gun. Loaded 6spf. With eel. Ran in hole with perf gun t07400. Ran collar strip and tied in to GR/CCL/Temp./ Press. Log dated 3/24/02 and open hole log. Pulled up to gun depth. Perforated 7" casing from 7289' to 7319' (30') 6 SPF Wire line Indicator showed guns fired @ 06:54 hrs. (1347 psig SITP on digital press. gauge) Had instantaneous 16 psig increase to 1363 psig SITP Pulled out of hole with Schlumberger wire line and laid down perf gun and lubricator. 1366 psig SITP @ 07:00. Drilling Turned well over to production @ 08:00 hrs 3-25-02 1367 psig SITP, and rig up to shoot fluid levels. Shot fluid level @ 6495' 1367 psig sitp @ 8:17 hrs. Bled down N2 cushion from 09:41 hrs to 10:01 hrs, bled from 1370 psig to 1077 psig SITP. Shot numerous fluid levels @ 11:12 hrs averaging 6500' 1086 psig SITP. Phil Ayers and Jimmy Childress called town for discussion on next plan of events. Production turned well back over to Drilling @ 12:00 hrs 3-25-02. Had 1077 psi on well. Picked up Schlumberger Gr/CCL/Temp/Press log. Picked up lubricator. Ran in hole to 7689' with logging tool to determine fluid level. Found fluid level at 7419'. Had 98' of fluid entry from 07:00 to 13:00 hrs (6 hrs). Pulled out of hole with logging tools. 98' of fluid = 3.64 bbls or .6 bbl/hr. Observed and monitored well. Picked up Pollard wire line's Sample Bailer on Schlumberger's wire line and ran in hole to 7468'. Picked up sample of fluid with bailer and pulled out of hole with wire line. Laid down bailer and sinker bars. Rigged down Schlumberger. Shut Down for Night. Discussed cement job with Dowell, Schlumberger, and Anchorage Office. Decided to load well with 6% KCL water and set cement plug. Ordered out equipment and materials needed. ,-~ ~ 3/26/02 Shut down for night. Called out equipment and materials for coil tubing cement job. Held safety meeting with coil tubing crew. Serviced and warmed up coil tubing equipment. Spotted open top tank and started receiving water for cement job. Started mixing 6% KCL water. Picked up injector and made up BHA. Stabbed injector onto tree top. Received and mixed a total of 140 bbls of cold 6% KCL water. Mixed 65 bbls of 85° warm 6% KCL water. Opened well and ran in hole with 1-3/4" Dowell coil tubing to 7729.5'. Tagged bottom (PBTD). Displaced nitrogen pad from well thru adjustable choke with max pump pressure at 2500 psi (coil tubing) Pumped a total of 146 bbls of 6% KCL water, had fluid to surface with "0" pressure on well. Left 65 bbls of warm KCL water in hole from surface to 4918'. Monitored well, had no nitrogen left in well. Held safety meeting and pre-job discussion with all personnel. Batch mixing cement to Dowell blender. Mixed 131 sx of class ""G" cement with .3% 0-65 (Dispersant) +.06% XE-920 (Retarder) + .2% D-46 (Anti-foam) + .3% 0-167 (Fluid loss). Mixed and blended cement at 15.8 ppg, yield 1.16 Cu. Ft./Sk. Total slurry volume, 27 bbls. Pumped 5 bbls of fresh water ahead of cement at 1.5 bpm with 1950 psi. Pumped 27 bbls of 15.8 ppg pre-blended cement at 1.5 bpm with 3300 psi. Pumped 1 bbl of fresh water behind cement at 1 bpm with 2000 psi. Pumped 5 bbls of 0-110 (Retarder) (in place of Biozan) at 1.5 bpm with 2500 psi. Had cement to end of coil tubing at 7729'. Picked up slowly laying in cement plug from 7729' to 7700'. While laying in cement, trapped 500 psi on well. Had cement clear of nozzle with 500 psi on trapped pressure on well. Pulled up slowly to 6850'. Pumped 15 bbls of 6% KCL water to clear coil tubing, maintaining 500 psi or less on well thru adjustable choke. Shut down pump and instantly lost complete returns. Attempted to re-pressure cement with 2 bbls of KCLwater at 1 bpm. Pressured up to 250 psi. Shut down pump, Tubing on vacuum. Pulled out of hole with coil tubing with out pumping. Monitored well for 30 min. well still on vacuum. Closed in well. Flushed coil tubing with 40 bbls of fresh water thru wing valve. Blew down coil tubing and surface lines with nitrogen. 3/27/02 Shut down for night. Safety meeting with coil tbg crew. Started and warmed up equipment. Ran in hole with coil tbg to 1700'. Had kcl water to surface, with 100psi. Continued in hole to 2000'. Observed well, well flowing. Closed in well. Pulled end of coil to lubricator. Had 100psi on well while pulling. Bled pressure to 0 with no flow. Observed well for 30 mins. No flow. Ran in hole with coil tbg to 6945' with 500psi on wellhead. Tagged cement plug. Bled 500psi to O. Had no flow. Observe well for 1 hour. Blended 60BBLS of 6% kcl water in Vacuum truck. Loaded coil with 33 BBLS of 6% kcl. Had fluid to surface. Closed in well and tested cement plug to 1750psi. For 15 mins, tested OK. Rigged up to pump N2, tested nitrogen pump and lines to 3500psi OK. Picked up to 6900'. Blew down well at 800scf/min. Recovered 124 BBLS of fluid from well bore and 33BBLS from coil tbg. Total recovery 157 BBLS, calculated recovery 129 BBLS + 33 BBLS from coil tbg. Calculated fluid level @ 6765.4'. Pulled end of coil to 4000'. Blew well dry. Had no fluid recovery. Total nitrogen used 1500gallons. Pulled out of hole with coil tbg. Trapped 500 psi on well. Rigged down coil tbg. Injector. Removed coil tbg. BOP from treetop. Repositioned equipment for E-line. Rigged up Schlumbereger wire line unit and wire line BOP, while rigging up Schlumberger. Shot 3 fluid levels down well bore, at 6400', 6470', and 6470. Picked up Gr/CCLlTemp.lPress. Logging tool. Picked up wire line lubricator. Rigged up A&K Rentals test 3/28/02 ,-.., i~ pump to test Schlumberger wire line lubricator. Tested Schlumberger lubricator to 500/3500 psi, ok. Running in hole with logging tools. Continued running in hole with Gr/CCLlTemp/Press log to 6954'. Tagged cement plug. Recorded fluid level at 6626'. BHT at 134°, BHP at 680 psi. Pressure at 5714' was 510 psi with 450 psi on wellhead. Logged from 6954' up to 3600'. Pulled out of hole and laid down logging tools. Rigged up Dowell to pump 1000 psi nitrogen pad to well. Attempted to pump nitrogen. Universal joint between Pump Engine and Dyno failed. Unable to pump Nitrogen. Called out Dowell mechanic to repair nitrogen pump. Mechanic arrived on location at 0630 hrs to inspect equipment breakdown for needed parts. Left location at 0715 hrs in search of parts. Waited on Dowell mechanic. Test ran engine without Dyno. Found engine will pump nitrogen without Dyno to heat nitrogen. Might need to pump at a slower rate. Pressured up on well from 450 psi to 1000 psi with nitrogen at 400 scf/min for nitrogen pad. Held safety meeting and pre job discussion with Schlumberger wire line crew. Tested circuits on guns. Picked up a 2" OD x 40' long HSD 2006 Power Jet perf. Gun loaded 6 spf. Picked up lubricator. Switched from dial type surface pressure gauge to digital gauge. Ran in hole with perf gun to 6600'. Tied in to Gr/CCL/log dated 3-27- 02. Set gons (Texas slang for guns) on depth. Perforated 7" casing from 5694' to 5734' at 17:34 hrs with theoretical 50 % under balance. Had 8 psi increase in pressure after 5 min. (pressure inc. from 972 psig to 980 psig SITP on Digital pressure gauge). At 17:40 hrs had 983 psig SITP. Pulled out of hole with perf guns. Inspected guns, all shots fired. Turned well over to production at 1830 hrs. Shot three fluid levels (6294', 6283', and 6303') from 19:21 to 19:28 hrs, all at 983 psig SITP. (Note: Previous fluid level shot at 20:00 hrs 3/27/02 was 6470' at 500psig SITP, so theoretical 180+- fluid level rise, but need to confirm with temp/press log). Turned well back over to Drilling at 2000hrs. Picked up Pollards ball type sample bailer with Schlumberger's Gr/CCLlTemp/Press log and ran in hole to 6602'. Found fluid level at 6596' (30' rise based on previous Temp/Press Log). Picked up water sample (sample #1and #2) from 6607' at 21:15 hrs and pulled out of hole with bailer. Turned well over to production at 22:00 hrs. Sent water samples to Baker Petrolite for chloride titration, waiting on results. Tested for combustible gas at choke skid with gas detector -none. Received water analysis results from Baker Petrolite at 23:50 hrs, Sample # 1 and sample #2 titrated at 17340 and 17060 ppm chlorides respectively. Original completion fluid in hole was 64000 ppm chloride 6% KCL fluid, so samples obtained were either formation water or formation wtr/ 6 % KCL mix. 3/29/02 Began RU SWS for perf job. Shot three fluid levels (6415', 6458', and 6459') from 00:29 to 00:36 hours, all 982 psig SITP. Bled down nitrogen cushion to tank from 982 to 836 psig. Shot two fluid levels (6280', 6293') at 01 :05 hrs, 838 psig SITP. Shot two fluid levels (6367', 6365') at 0135 hrs, 838 psig SITP. Turned well over to Drilling at 01 :30 hrs. Tested circuits on guns. Picked up a 2" OD x 35' long HSD 2006 Power Jet perf. Gun loaded 6 spf. Picked up lubricator. Ran in hole with perf gun to 4200'. Tied in to Gr/CCL/log dated 3- 27-02. Perforated 7 " casing from 4008' to 4043' at 0353 hrs with theoretical 50 % under balance (assumes 1812 psig res pressure). Had good eline Movement during firing. Had 8 psi increase in SITP after 5 min. from 838 psig to 846 psig SITP. At 0400 hrs had 852 psig SITP. Pulled out of hole with perf guns at 0430 hrs had 925 psig SITP. Inspected guns, all shots fired. At 0500 ~ ,"""", hrs had 979 psig SITP. Turned well over to production at 0500 hrs. Shot fluid levels but uninterpratable in casing. Prepared to flow well. Air hose to separator unit frozen - blew clear. Final SITP prior to flow 1085 psig. Opened well to flow from perforations 400'8-4043' and 5694' and 5734 on 28"/32" choke blowing nitrogen cushion to flare. Initial rates eight minutes into blow down at 0607 hrs were 3.1 MMCF/D (nitrogen) at 780 psig FTP. Pressures and rates reduced rapidly. Attempted to shoot fluid level at 0626 hours - unable to interpret. Pressure and rates continued to reduce rapidly to 1.0 MMCF/D at 379 psig FTP at 0633 hrs (34 minutes in to flow) into flow). Closed back pressure valve on separator and SI well. Discussed utility of remaining nitrogen cushion for plug back operations with drilling engineer. Well SITP built to 983 psig during this time. Resumed nitrogen blow down at 0734 hours on 92/64" choke at initial 2.8 MMCF/D. Rate and decline rapidly to 400 psig FTP at 0739 hours. Opened back pressure valve on separator to maintain rate. Improved rates momentarily to 2.3 MMCF/D but rapidly dropped to 1.5 MMCF/D at 127 psig FTIP by 0745 hrs Had combustible gas to surface at 0749 hours Flared gas for 91 minutes as follows averaging only 0.125 MMCF/D. Total gas produced estimated at 8 MCF. 0749 hrs, measured at 0.50 MMCF/D at 32 psig, 16 ft high flame (took picture), took gas sample #1 0750 hrs, estimated 0.25 MMCF/D at 11 psig, 8 ft high flame (took picture), took gas sample #1 0755 hrs , estimated 0.125 MMCFID.at 6 psig, 4 ft high flame, took gas sample #20815 hrs, estimated O. 0626 MMCFID at 4 psig, 2 ft high flame 0904 hrs, estimated 0.0315 MMCF/D at 3 psig, 1 ft high flame 0920 hrs, Well died while RIH with Schlumberger's Gr/CCL/Temp/Press logging tool with Pollard sample bailer. Turned over well to drilling at 0900 hrs. Picked up Pollards wire line ball type sample bailer on Schlumberger's Gr/CCL/Temp/Press logging tool. Ran in hole to 1285'. Found fluid level at 706'. (Picked up fluid sample and pulled out of hole. T0tal fluid rise since perforating in well is 5890 ft over 6 hours (approx.1 000' ft.,.¡se /hr). Unloaded sample bailer. Had water with oil and sand mixture. Well died while running bailer. Samples sent in for analysis to Baker Petrolite (sample # 1 and sample #2 have 1040 and 980 ppm chlorides). Ran in hole with Gr/CCL/Temp/Pressure log to 6948' (had approx. 6' of fill on top of cement plug). Detecting zone fluid Movement with Pressure and Temperature log. Production recording and evaluating log information with Schlumberger Engineer. Pulled out of hole with wire line. RD Schlumberger. Some temperature cooling exists at 5690' to 5670' and temperature flattening at 5996-5991. Jesse Cryer with Schlumberger to provide analysis on log in morning. Turned well over to Production at 1330 hrs. Shut in well at 1604 hrs 2 psig SITP. Waiting on decision on type of well work 3/30/02 Monitored and observed well with open perfs from 5694' to 5734' and 4008' to 4043'. Well has had 10-11 psi on tubing since 0200 hrs. 3/31/02 Monitored well, TBG @ 12psi sitp, shot fluid levels 2,362',364'. 4/02/02 Loaded out test equipment and hauled to Griner. Pearl #1 Sununary of Logs Run LO2 Run Surface Run #1 Surface Run #2 TDRun#1 TD Run #2 Cased Hole Perf Runs ~ Depth Interval 1792' - 0' 1792' - 78' 8000' -1792' 8000' - 78' 7853' - 3600' 7799' - 3600' 7799' - 7100' 7700' - 3600' 7689 - 3600' 6954' - 3600' 6948' - 1285' ,~ LO2S Date Caliper Log 2/18/02 Platform Express (PEX-AIT) 2/19/02 Triple Combo 3/05/02 CMR-ECS-GR-DTC VSP 3/06/02 GR/CCL 3/19/02 GR/CCL/Press/Temp 3/20/02 GR/CCL/Press/Temp 3/21/02 GR/CCL/temp/pressure 3/24/02 Gr/CCLIT emp/Press 3/25/02 Gr/CCLIT emp/Press 3/28/02 Gr/CCLlTemp/Press 3/29/02 J. fx¡x: -e? ~ r-.., Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950 I Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unoca1.com UNOCAL8 Beverly Harrison April 23, 2002 Business Ventures Assistant To: AOGCC Lisa Weepie 333 W. ih Ave. Anchorage, AK 99501 DATA TRANSMITTAL - PEARL #1 qOò-OIl LOG TYPE SCALE LOG DATE INTERVAL CO MEDIUM 2" HSD PJ GUN 5 INCH 19-Mar -02 7500-7853 1 B-Line ~ 2" HSD PJ GUN 5 INCH 19-Mar-02 7500-7853 1 Film v COMPLETION RECORD - CEMENT BAILERS 5 INCH 21-Mar-02 7550- 7755 1 B-Line ¡.y COMPLETION RECORD - CEMENT BAILERS 5 INCH 21-Mar-02 7550-7755 1 Film v FINAL WELL REPORT 05-Mar-02 1 Paper ~ LAS DATA 1 RW EXPLORER FILES 1 PDF FILE ON 05-Mar-02 1 CD \X CD ROM POWER PULSE - GAMMA RAY 2/5 INCH 17 -Feb-02 1780-7257 1 B-Line IX" GAMMA RAY 1 CCL 1 PRESSURE 1 TEMPURATURE 51NCH 25-Mar-02 3850- 7700 1 B-Line lK' 1 TOP OF FLUID DETERMINATION GAMMA RAY 1 CCL 1 PRESSURE 1 TEMPURATURE 51NCH 25-Mar-02 3850-7700 1 Film ¡/ 1 TOP OF FLUID DETERMINATION COMPLETION RECORD - 2" HSD PJ, 30' GUN 5 INCH 25-Mar-02 7400-6950 1 B-Line lk' COMPLETION RECORD - 2" HSD PJ, 30' GUN 5 INCH 25-Mar-02 7400-6950 1 Film v ARRAY INDUCTION 1 MCFL 1 DENSITY 1 NEUTRON 2/5 INCH 18-Feb-02 0-1800 1 B-Line V IGRISP/CALIPER ARRAY INDUCTION 1 MCFL 1 DENSITY 1 NEUTRON 2/5 INCH 18-Feb-02 0-1800 1 Film IX IGRISP/CALIPER CALIPER LOG 5 INCH 18-Feb-02 0-1792 1 B-Line lY' CALIPER LOG 5 INCH 18-Feb-02 0-1792 1 Film v COMBINABLE MANETIC RESONANCE TOOL 5 INCH 05-Mar-02 1700-8000 1 B-Line \Y'" COMBINABLE MANETIC RESONANCE TOOL 5 INCH 05-Mar-02 1700-8000 1 Film v NATURAL GAMMA RAY TOOL 51NCH 05-Mar-02 1791-7994 1 B-Line i'( NATURAL GAMMA RAY TOOL 5 INCH 05-Mar-02 1791-7994 1 Film v ELEMENTAL CAPTURE SPECTROMETRY 5 INCH 05-Mar-02 1700-8000 1 B-Line ~ ELEMENTAL CAPTURE SPECTROMETRY 5 INCH 05-Mar-02 1700-8000 1 Film ./ CALIPER LOG 2/5 INCH 05-Mar-02 1791-7994 1 B-Line ~ CALIPER LOG 2/5 INCH 05-Mar-02 1791-7994 1 Film ,,/ Please acknowledge receipt by signing and returning one copy of this transmittal or~~ ftÎ~ Received By: ~ø, ~~ ") Date: 1 tPP 2. /( 2.002. Alaska Oil & Gas Cons. CommisSion Ancborage "--" ,-.. ARRAY INDUCTION I DENSITY I NEUTRON I DSI I 2/5 INCH 05-Mar-02 1791- 7994 1 B-Line ~ GR ARRAY INDUCTION I DENSITY I NEUTRON I DSI I 2/5 INCH 05-Mar-02 1791-7994 1 Film V GR FORMATION MUD LOG 2 INCH 17 -Feb-02 300-8000 1 B-Line v' CMR DMRP PROCESSING 2 INCH 05-Mar-02 3900-8000 1 B-Line )( ELAN CLOBAL SOLVER 2 INCH 05-Mar-02 3900- 7840 1 B-Line vY CMR INTERPRETATION PORE SIZE 05-Mar-02 1 B-Line / DISTRIBUTION CMR INTERPRETATION PORE SIZE 05-Mar-02 Paper ..x DISTRIBUTION REPORT GR/CCLI PRESSURE I TEMPERATURE ITOP OF '/5 INCH 24-Mar-02 3550-7700 1 B-Line ~ FLUID DETERMINATION GR I CCL I PRESSURE I TEMPERATURE I TOP OF ~5 INCH 24-Mar-02 3550-7700 1 Film v FLUID DETERMINATION COMPLETION RECORD MECHANICAL PLUG BACK 51NCH 21-Mar-02 7100-7767 1 B-Line v( TOOL COMPLETION RECORD MECHANICAL PLUG BACK 51NCH 21-Mar-02 7100-7767 Film V TOOL GR/CCL/PRESSURE/TEMPURATURE 5 INCH 19-Mar-02 3550- 7853 1 B-Line vt GR/CCL/PRESSURE/TEMPURATURE 51NCH 19-Mar-02 3550- 7853 1 Film ¡/ GR/CCL/PRESSURE/TEMPURATURE 5 INCH 20-Mar-02 3550-7799 1 B-Line / GR/CCL/PRESSURE/TEMPURATURE 5 INCH 20-Mar-02 3550-7799 1 Film V PEX I NGT I DSI2 I CMR +3 CSAT 05-Mar-02 1 CD 1 of 2 « PEX I NGT I DSI2 I CMR +3 CSAT 05-Mar-02 1 CD 2 of 2 ~ AIT I DENSITY I NEUTRON 18-Feb-02 1 CD .x FORMATION EVALUATION LOGS I SURVEYS I 28-Feb-02 1 CD -i. LWD DATA Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: ~ ~f2'-^- ) RECEIVE£: Date: 2 ¡rp 2 /. I)OO? " " ,Lv- Alaska Oil & Gas Cons, Commisaion Anchorage ~ ,----, fr,rdl.p o~ Y¿ ;7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ----- 1, ìyp<:: of ReCu""t: Abandon: Suspend: Operation shlJtdown~ Alter casing:-- Repair well: Plugging: X Change approved program: Pull tubing: Variañœ: 5. rÿpeë)fweIJ: Development Exploratory: X Stratigraphic: Service: T Name of Operator UNOCAL ,"-"'--"""""'-""""'--"" 3. AddfëSS PO BOX 190247 Anchorage,Alaska 99519 -4. Location of~ell atsürtace 1568' fNl, 1968' fWL, Section 24, T1S, R14W, 8M At top of productive interval 1568' FNL, 1968' FWL, Section 24, T18, R14W, 8M At effective depth 1568' fNL. 1968' fWL, Section 24, ns, R14W, SM At totai deptt\ 1568' FNL, '1968' FWL, Section 24, TiS, R14W, 8M 12. Pfe~nt well col1ditic»)1 summary Total depth: measured true vertical 8,000' 8,000' E.fft'dÎve depth: measured 7,755' trUE;¡ vertical 7,755' Casing Length structural Conductor 95' Swfélct; 1,791' tnt"nnedJ"ta froduction '7,983' Liner P,;¡rlù..ation depth: measured Size 13-3/8" 9-518" 7" 7,799'-7,835' (plugged) true vertical 7,799'-7,835' (Plugged) Tubing (size, grade. and measured deplo) 3.1/2", 9.2#. L-80, Imp Buttress @ 3,769' P¡;¡í:;kBf.. and SSSV (type and measured depth) ~~k",r, SAB @ 3,706' 1:3. A.ttachement$' , Description summary of'proposal: X "14:'"Estlmatëd dat~ for c~'mmencing operation 3/26102- 16. If propõsaì wei(verbaIÎÿ"i;pproved: feet feet Plugs (measured) feet teet Junk (measured) Cemented Driven 532sx 1 st stg 560 sx 2nd stg 393 $X 7,289'-7,319' 7,289'-7,319' Re-enter suspended well: Tìme extension: Stimulate: Perforåtë: Other: - 6. Datum elevation (OF or KB) 225.8 7. Unit or Proparty"ñame feet South Ninilchik 8. Well number Pearl No.1 9, Permit number' 202-011 10. API number 50-133-20509-00 1 i. Field/Pool South Nlnllchlk Prospect 7.755' RECEIVED MAR 2 6 2002 Measured d~ka Oil & XSB£~WC¡JPJSSton 95' 1,791' 95' 1,791' 7,983' 7,983' ,""'r\~ t""':-;',,"""II.ITH1- .',' l'i,;~ ~'f,~~,,)~,rq¡. ¡J,',~ï.~ , )'\""'J,tt¡f"'~ !!ii""~~~ :" I:: ,$, ~' "u, ,! '" ," ;.:, JO,U;o:;, c." ;., >0 ", . """ ~, Detailed operations program; BOP sketch: Oil: 15. Status otwell classificatIon as: Gas; X Suspended: - I~ame of approver .., Date approved Servîoo; "17" i 'hërebY~;~~há::;~ :e~~~s truf&;Rrre~~~ be7:j ~~~;e~ J; fYJ Signt:d: I Dan Williamson Title:" Drilling Ma~_ager ------ -"'" ",.. ,'" -- FOR COMMISSION USE ONLY '2' A-r=tll.. ð 2- Date: COllóidOJI£ of ilPProval: NO)( Commission 50 repre5e~tatîVQ may witness , ¡Approval No, Plug h¡tegrlty BOP Test- Location clearance , t' ' I < ~('};)-I OÎ", MechÓlnlcaJ Integrity Test- Sub$EiCl,Ient form required 10- '-\~ ('~w~\f Approv,"d"by order of the Commissioner Form 1 0-403 Rev 06/15/88 Z/Z 'd 6899'ON Original Sìgned By Cammy Oechsli ORIGINAL 'd~OJ lVJONn Commissioner Date 36q~~ SUBMIT IN4~LI¿~ ~d90:9 ZOOZ '9Z'Je~ . Re: Pearl 7300 Sand Abandon ~ ,.-,., Subject: Re: Pearl 7300 Sand Abandon Date: Tue, 26 Mar 2002 17: 14:24 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Brandenburg, Tim C -Contract" <brandenburgt@unocal.com> CC: Bob Crandall <bob_crandall@admin.state.ak.us>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tim, This note confirms our discussion regarding the proposal to P&A the intervals from 7289 -7~~9 and perf~rming a minimal squeeze. Your proposal is acceptable. The only addition as we discussed would be to tag the plug when you are in the hole to "blow" the fluid out of the hole with nitrogen. Please provide the number for the location as I may have one of the Inspectors go by to witness the tag. Also, please provide the information as to what pressure you plan to test you CT BOP. Good luck, Tom Maunder, PE AOGCC "Brandenburg, Tim C -Contract" wrote: > T/GHT HOLE > > A TTENT/ON: The well data and information included in this em ail and its > attachments is the confidential property of UNOCAL and its partners and is > not to be shared with or distributed to any other parties or persons. If > you feel you have received this information in error, please delete it after > contacting the sender. > > Tom, > > Yesterday (3/25/02) we perforated the Pearl No 1 from 7,289'-7,319' MD/TVD > with 50% drawdown at mid perf. The zone contributed 3.64 bbls (98' of fluid > rise) in 6 hours as indicated by Pressure/Temp. log data and no methane. As > of this AM there was no measurable increase in pressure. We intend to > abandon the perforations as follows: > > 1) RIH with Coil Tubing. > 2) Lay 15.8ppg cement plug from 7730' (PBTD) to 7000' covering the perfs > with 289' of cement > 3) Apply 500 psi downsqueeze pressure and maintain positive pressure for 12 > hrs. > 4) Pressure test plug to 1750 psi > > Please see the actual and proposed schematics below. I will fax over the > 10-403. > > Thanks, > > Tim > > «Pearl Actual Sch 3-25-02.doc» «Pearl Prop Sch 3-26-02.doc» > > --- ---- ---- -- -------- ---- ---- ------ ----- ---- ---- -- ---- ------ ----------- > > > > > > > c.~w-,Q t\.-\- ~ ~"",,J2:: c:.u.. ,<:.~ \Ci... ~t:> ~C) ,;),\, \ "o~\~ ~S'~\Cc ~ ~\)~~ '\ \\\> ~ 5>\-'\ \ \ \r-,"'-~Q- \~ Ð'-<:'~.:\- <Å '00 '-.) <ê:. ~<t \ ~ j çJ ?~ ~6t.. Name: Pearl Actual Sch 3-25-02.doc Pearl Actual Sch 3-25-02.doc Type: WINWORD File (application/msword) Encoding: base64 Name: Pearl Prop Sch 3-26-02.doc Pearl Prop Sch 3-26-02.doc Type: WINWORD File (application/msword) Encoding: base64 1 of 2 3/26/025:16 PM . - UNOCALe ELEVATION: 222.5 Feet ACTUAL RKB = 17.37 1 - - 2 : ~ -4 ; ¡ j ¡ .... I j ; ¡ , ¡ 3 . 1 :Q~ 4 5 , L...i ~ ,. . tJ PEARL # 1 PTD = 7,853' ELM TD = 8,000' Vertical ~ ~OUTH NINILCHIK Well PEARL # 1 Proposed Completion 3/26/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-318" 61 K-55 Butt 12.515 Surfuce 95' 9-5/8" 47 L-80 Butt 8.681 Surfuce 1,791' . 7" 26 L-80 Butt Mod 6.276 Surfuce 4,445' 7" 29 L-80 ButtTKC 6.184 4,445' 8,000' 6 Tubing .. 3-1/2" 9.2 L-80 Butt SC 2.992 Surfuce 3,788' 3/8" .25 416 SS Continuous .25 Surfuce 1,968' JEWELRY DETAIL NO. Depth ID OD Item 1 17.37' 2.992 11" Tubing Hanger, 3-1/2" 2 1968' 2.990 5.437 Chemical Injection Mandrel 3 3706' 2.990 SAB 40-32 Baker Packer 4 3,754' 2.661 "XN" Nipple 5 3788' 2.990 Shear Out Ball Sub wi W/L Entry Guide 6 TBD Methanol Injection Line Perforations Date Zone Top BTM Length Comments 3/19/02 7800 7798' 7836' 36' 2", PI, 6spf, 60 deg 3/25/02 7300 7289' 7319' 30' 2", PJ, 6spf, 60 deg I Proposed' TOC 7000' § I Perfs 7289'-7319' I Plug at 7755', TOC = 7730' J . I Perfs 7799'-7835' I - DRAWN BY: I.I.M. REVISED: 3/15/02 TCB .. .-.., ~OUTH NINILCHIK Well PEARL # 1 Actual Completion 3/25/02 . - UNOCAL8 ELEVATION: 222.5 Feet ACTUAL RKB = 17.37 1 .. ' ¡ J ¡ ¡ ¡ : ¡ ; ! ¡ ¡ ¡ ! - SIZE WT 13-3/8" 61 9-5/8" 47 7" 26 7" 29 Tubing 3-1/2" 9.2 3/8" .25 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. K-55 Butt 12.515 Surfàce 95' L-80 Butt 8.681 Surfàce 1,791' L-80 Butt Mod 6.276 Surfàce 4,445' L-80 Butt TKC 6.184 4,445' 8,000' L-80 Butt SC 2.992 Surface 3,788' 416 SS Continuous .25 Surfàce 1,968' - , , , j ¡ j t t ¡ 6 - at JEWELRY DETAIL NO. De"llth ID OD Item 1 17.37' 2.992 11" Tubing Hanger, 3-1/2" \ 2 1968' 2.990 5.437 Chemical Injection Mandrel .... 3 3706' 2.990 SAB 40-32 Baker Packer 2 ¡ 4 3,754' 2.661 "XN" Nipple 5 3788' 2.990 Shear Out Ball Sub wi WIL Entry Guide zj ,. 3 ~ 6 TBD Methanol Injection Line ---- Perforations 4 U 5 Date Zone Top BTM Len~th Comments 3/19/02 7800 7798' 7836' 36' 2", PI, 6spf, 60 deg 3/25/02 7300 7289' 7319' 30' 2", PI, 6spf, 60 deg ê I Perfs 7289'-7319' I Plug at 7755', TOC = 7730' '~.IL.ðJþ~. = I Perfs 7799'-7835' I J J PEARL # 1 PTD = 7,853' ELM TD = 8,000' Vertical DRAWN BY: J.I.M. REVISED: 3/15/02 TCB /""'. ~ ~ ~ Á ~ t.f/ï ~ -- 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRQV ALS Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing:- Repahell: Plugging: X ~ Time extension: Stimulate: , "..,.. , """, ,.', .._....~~~)ge approved program: Pull tubing: Vé\rlance: Perfor;õta: Otl1et: - 2, Name of Operator' ,'" ......,.., '5~..type of-":V&II: 6. Datum elevation (OF or KB) UNOCAL Development: 225,8 ~3. Addr"ss Exploratory: X 7, Unit or Property name Stratigraphic: Service: 7.799'.7,835' true vertical 7,799'-7,835' Tubing ($ìze, grade, and measured depth) 3-1/2", 9.2#, L-80, Imp Buttress @ 3,789' Paèkers and S5SV (type and measured depth) ...", ,-",..ß¡¡l(er,SAB@3,706' " 13, Atlacheme(¡ts Description summary of proposal: X --1-4':'"E$thnated date forcómmanèing operation' ~1M - 16, If proposal well ~erb~lIy¡¡pproved:' ~ 1'\ Oil: - Gas: ~ lorn fv1¡¡undar IA <rvv1 )R:(c 0. ~ ~/20/02 Name of approW- ' r ~ ,- Date approved Service: T7~-1 he, r~ ' ~iiry t~" 'th~f9 lng, is t~ue nd correCt to the best of my knowledge. , ,(¡ f /1 ¡~a ',Ai '\ Signed, )J'~~", ' f¡,\J~ i Williamson Title:, Drilling Manager ".. , , ' \ " fOR COMMISSION USE ONLY Conditions of ~ppròval: Notify-Õommission so repr¡¡sentative may witnešš Plug integrity BOP Test- Location clearanœ~ ~ I) Mechanicallnlegrity Te5t- Subsequent farm required 10- "\.40 \'\ ~ "-~ e~~\.\ ....' ........... ,.. ....' .. I. Typ", of Requðs!: PO BOX 190247 Anchorage, Alaska 99519 4. Loca!ionòfwsll ai:surfaca 1568' FNL, 1968' FWL, Section 24, ns, R14W, SM At top of productive inteIV¡J1 iS68' FNL, 1968' FWL, Section 24, T1S, R14W, 8M At effi¡;ctiv~ depth 1561)' fl'lL, '1968' FWL. Section 24, ns, R14W, 8M At total depth 1568' FNL, '1968' FWL, Section 24, T1S, R14W, SM '1'2:Present well condition sumniåiy Tot..1 d,;,pth: measured true vertical 8,000' 8,000' Effe<-'tive depth: measured ;,953' true vertical 7,953' C<\i>il1¡'j Length Structural Conductor 95' Surface 1,791' Intermediate Production 7,983' lilIaI' PerfOration dapEh: measured Apploved by order of the ComrnÎs5ioner ~-- ,...., ,.. Form '10-403 Rev 06/15/88 t /3 'd 8199'ON feet South Ninilchik 8. Well number Pearl No, 1 9, Permit number 202-011 10, API number 50-133-20509-00 11. Fleld/Pool South Ninilchik Prospe<::t feet Plugs (measured) feet feet Junk (measured) f¡¡et Size Cemented Measured depth ,,' 13-3/8" Driven 95' 9-518" 5325)( 1,791' 7" 1 st stg 560 sx 7,983' 2nd stg 393 sx True vertical depth 95' 1,791' 7,983' CONFIDENTIAL Detailed operatîons program: BOP sketcl\: 15, Status of well classification a5: Suspended: - Date:..'J-JÀ "02 APproval N~, " .:)~-JQ~ RECEIVED Original Sìgned BV åarrr ~cr1~ A L MAR 222002 ~') , ..~ ' Commissioner Alaska Oil &~S Cons. co""J....íl I Z- " .. AnchoriiUe l~".., , SUBMIT IN TRIPLICATE 'd~O:) 'W:)ONn ~d9 l : 9 ZOOZ 'ZZ'H~ ~" ~ ~. Brandenburg, Tim C -Contract ."""""",,""""""'-""""""""" -',,"""---- From: Sìint: 10: Subject: Tom Maunder [tom~.maunder@adm'J1.state.ak,us) Wednesday, March :20, 2002 3:55 PM Brandenburg, Tim C -Contract Re: Pearl No, 1 7800 Sand Abandon -~-_J C,;,rtJ tor '1'0111 t;l;;U¡1áer Tim, As we discu$sed and reviewed with the regs, your proposal is acceptable. You will need to se~d in a 403; If it "'{arks for you, fax it over (make sure you sign It) and I will attach thiS em811 and your attachment. Good luck with the remaining testing. Torn Maunder, PE AOGCC "Brandenburg, Tím C -Contract" wrote: > > Torn, » :> ;;> Please disrsgaurd the first e-mail as I did not include the tight hole > > disclaimer. » :> ;> Thanks, » > > Tin\ > > > > :> > TIGHT HOLE :» > ;;. ATTENTION: The well data and information included in this email and its :> > attachments is the confidential property of UNOCAL and its partners and is :;. > not to be shared with or distributed to any other parties or parsons. If > ;. you feel you have received this information in error, please delete it :> > after Gùntactîng the sender. >;. » :> > Torn, ;;> :;. > :> Yesterday, 3"1~-.Q4, w~ perforated the first zone at the Pearl No. i. We > ;... pe¡fol'aled 7799-7835' (36') with a 50% drawdown at mid perfs assuming a :> > reservoir pressure of 3517psi (.45 psi/ft gradient). The well had a > > minimal inflow of water (Confirming fluid level with e-line, Echo meter > :> indicates 1000' of rise in 19hrs with a 70% drawdown on the reservoir). > > We are considering this Zone to be extremely tight and non productive. As > > such we are pr()posing to set a PosÎset plug at approx 7755' and dump bail :> > 25' of cernent on top of the plug in order to abandon and allow for testing > :;, of zones above. Please see that attached Schematic. Our plan is to :> ;;. cOIilpJete diagnostîcs this evening and then commence plugging, If you have > > any questions please call. > :> :> >Tim » > > «Pearl Prop Sch 3-20-02.doc» :> :> -~ -"., - ---.w ~~- - -. --- w- -- - - --- -~ - - --.- -- ------ -- - - ---- - ----- ---- -- --- > Name: Pearl Prop Sch 3-20-02.doc Pearl Prop Sch 3-20-02.doc Type; WINWORD File (appJication/msword) Encoding: base64 > > RECEIVED MAR 2 2 2002 Alaska Oil & Gas Cons. GOHJíTilSSiO!' Anchorage CONfIDENTIAL 1 j¡ /~ . ,1 R i q q , 0 ¡'J 'd~Oj WjONn ~d9 I : 9 zaaz 'ZZ'H~ "l(';~..........."'....I:88.... ...... , ~~ ~~ ~ UNOCAL8 .ELEVATION: 2.22.5 Feet ACTUAL rom = 17.37 '."""""r"u ,,' - " , ¡ ¡ ::,¡ I: ó - ','I ::1 ',; ::" !, 2 3 4 5 0 ,~ .. - SIZE 13-3ïS;' 9-5/8" 6 ~th 17.37' 1968' 3706' 3,754' 3788' TBD WT 61 47 26 .29 9,2 .25 § I Proposed Perfs 7289'-7319;'1 7" 7" TubIng 3-1/2" 3/8" NO. t 1- 3 4 5 ~ SOUTH NINILCHIK Well PEARL # 1 Proposed Completion 3/20/02 CASING AND TUBING DETAIL GRAD:E CONN m K-55 Butt 12.515 L-80 Butt 8681 TOP SuIfacc' Surface BTM. 95' \,191' r~ I pr~posed Plug at 7755" -, ':"'-S"1 ~ I Perfs 7799'-7&35' I r U l.[. PTD "" 7,853' ELM TD = 8,000' PEARL # 1 Ve..tical t/t'd 8199'ON L-80 L-80 Butt Mod Butt TKC 6276 6.184 SuIÍace 4,445' 4,445' 8,000' L-80 41655 Eutt $(; Continuous 2.99;2 ..25 5ut'f~e Slllface 3,788' 1,968' ID 2.992 2.990 2.990 2.661 2.990 JEWELRY DETAIL OD Item 11" 1\Jbing Hanger, 3-112" 5.437 Chemical Iujecrion Mandrel SAB 40-32 Baker Packer "XN" Nìppl<J Shear Out Ban Sub wi W/L Enuy Guide Mlilthauol1njlilotion Line Perforations Date Zone Top BTM Length COllunent9 3/19/02 . .,. 7800" ,. . 779F/' '1836' 36' 2", PI; 6spf, 60 deg 7300 7289' 7319' 30' Proposed CONfiDENTIAL RECEIVED t1AR 2 2 2002 Alaska on & Gas ÜOn!i,. GO@1USSIOíl Anchorage DRAWN BY: J.I.M. REVISED: 3/15/02 TC~ 'd~OJ lVJONn ~dLi:9 ZOOZ 'ZZ'Je~ ~ "-", Date: '"3:. .,-'2-,~-D<:, UNOCALe ,- " "'".'"' .'. \" """'",., To: .. ~ Name: r~~ Company: Fax Number. Phone: Number of P8¡es:!:I-lnduding tover sheet. From: 'n ' ' . "':f,fI"-'-- Nanw: <-;:." / Q::>.~ ¡LA, A"vv-...J' þ~ A~ntion A'"v ~ Fax Number. .~--. :-/ .,~' ,.'. . - ,nnr "-' 71' ('{.."O, -'..11: ("e'.,,' "N~~ ~~~::::. ' , þ}?~~ epAJ'1'J5. c"\r~" '::):::;:~,:', " \, ,- ~"""'" 'f"" "'"... ..,., , " ,.","'.' d, ,."",.,." .,r..I" "',""""" ,..,)"",:' .~.',:~:'" ,,",,>,~':-' """"'~" \w~,.~ :,.,..",;,i .. ,."".... ",w" ........'......' .. ",tu Subject: ~L. f-.-Jð ~ ( ..If' ..' .~.J. 'T ,,"Co"" ". CONfIDENTiAl '" " 'IltcflvE D' . ' MAR 2 2 2002 ~ au i Gas Cons. Commission Anchorage .. __..M,--'-~"--"'_"- v/'i"d 8\99'ON 'dHOJ WJONn Wd91:9 ¿006 '¿¿'JeW ~' ""'..d ~ Unocal /"""\ aQ3-0tl Schlumberger Pearl #1 CMR Interpretation Pore Size Distribution Company Field Well Date Logged Date Processed Reference Number API Number Log Analyst Union Oil Company of California South Ninilchik Pearl #1 5-Mar-2002 13-Mar-2002 22101 50-133-20509-00 R. Heath Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in OUI current price schedule. ,,--..., '---. Union Oil Company of California Job Number 22101 Well PEARL #1 Field South Ninilchik A. Processing Intervals The following depth intervals were requested for CMR Grain Size / Pore Size Analysis: 1 ) 4000 - 4050 2) 4130 - 4200 3) 5040 - 5075 4) 5450 - 5520 5) 5690 - 5740 6) 5825 - 5940 7) 6090-6130 8) 6560 - 6610 9) 7080 - 7120 10) 7280 - 7320 11) 7555 - 7590 12) 7670 - 7730 13) 7795 - 7835 ~, Union Oil Company of California Job Number 22101 1) 4,000- 4,050 feet Data Source: Data Sampling Rate (1'1). Cartridge/Sonde Numbers: CMR-Plus logging Mode: Stacked Depths (1'1): Parameter Summary: Estimated Polarization Time (s) : Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms): Number of Componen1s: Timur/Coates PHI T Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3) : T1¡T2 Ratio Minimum: 0.5 T1¡T2 Ratio Maximum: 3 Polarization Corr Threshoid (ft3¡ft3): 0.02 Bin Porosity Cutoffs (ms): 30 Very Fine Silt Clay 25 c iii >- :: 20 0 i ~ 15 .II 12.0 .5 J ':-- Pore Size (urn) 0.02 Grain Size (urn) 3.14 T2 Log Mean (ms) 0.5 0.0$ 7.75 1.8 7.995 1.255 1800 1 Auto 200 Total CMR Porosity On Off Off 0.3 30 4 2 0.02 0.3 0.02 0.02 30 10 3 10 r". Well PEARL #1 Field South Ninilchik CMR_ECS_023lUP.processed_am - cryer (Project Use 0.625 77174 Expert Depth log - B Mode 4050 to 4000 Starting Echo: EPM Processing: Logging Speed (ft/h): T2 MaXimum (ms): 3000 T2 Peak Search Maximum (ms): 750 SDR PHITExponent: SDR T2log Exponent: Porosity Threshold (ft3/ft3): T2 Threshold (ms): 33 100 300 1000 3000 Medium Silt Pore/Grain Size Distribution Medium Sand 16.2 0.1$ 18.10 6.3 Coarse Silt 18.$ 0.5$ 38.75 18.6 Very Fine Sand Fine Sand 19.0 18.4 1.76 8$.55 58.6 4,94 178.$1 1$4.8 13.18 354.75 438.3 First On From CS Arr<lý 4 2 0.4 10 Coarse Sand ---!:L 54.10 953.36 1803.4 r"" Union Oil Company of California Job Number 22101 2) 4,130 - 4,200 feet Parameter Summary: Estimated Polarization Time (S¡: Acquisition Idle Time (5): Number of Echoes: Repetition Count: Regularization: Echo Spacing (uS¡: Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (mS¡: Number of Components: Timur/Coates PHI T Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3!ft3): T11T2 Ratio Minimum: 0.-5 T11T2 Ratio Maximum: 3 Polarization Corr Threshold (ft3!ft3): 0._0.2 Bin Porosity Cutoffs (mS¡: 35 Clay 30 !: ¡¡¡ :z,. 25 :t= 10 2 a. 20 ~ .tI 15 .5 1: ~ 10 i 6.3 :--- Pore Size (um) 0.02 Grain Size (um) 3.30 T2 Log Mean (mil) 0.6 Data Source: Data Sampling Rate (ft) : Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stac~d Depths (ft) : Fine Silt 12.0 0.06 7.96 1.9 7.995 1_255 180.0. 1 Auto 20.0. Total CMR Porosity On Off Off 0._3 3D 4 2 0._0.2 0.-3 0.0.2 0._0.2 3D 10. 3 10. ~, CMR_ECS_0.23LUP-processed_anr - cryer 0._625 71174 Expert Depth Log - B Mode 4200 to 4130. Starting Echo: EPM Processing: Logging Speed (ft/h): T2 Maximum (ms): 30.0.0 T2 Peak Seard1 Maximum (ms): 750. SDR PHIT Exponent: SDR T2Log Exponent: Porosity Threshold (ft3Ift3): T2 Threshold (mS¡: 33 1 DO 30.0. 10.0.0 30.00. Medium Silt Pore/Grain Size Distribution Medium Send 22.1 0.19 18.24 6.3 Coarlle Silt 22.3 0.54 38.09 18.1 Very Fine Send Fine Send 18.0 14.8 1.76 86.81 $8.8 4.99 179.79 166.4 12.01 332.49 400.4 Well PEARL #1 Field South Ninilchik (Project Use First: On From CS Array 4 2 0.4 10 Coarlle Send 0.2 $0.19 904.61 1673.1 ~. Union Oil Company of California Job Number 22101 3) 5,040 - 5,075 feet Parameter Summary: Estimated Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us): Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms): Number of Components: Timur/Coates PHI T Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3l1l:3): T1ff2 Ratio Minimum: 0.5 T1ff2 Ratio Maximum: 3 Polarization Corr Threshold (ft3!ft3): 0.02 Bin Porosity Cutoffs (ms) : 35 Very Fine Silt Clay 30 c ìii >0. 25 :t:: .. 0 ã. 20 .c <> .D 15 .5 1: l':-- Pore Size (um) 0.02 Grain Size (um) 3.32 T2 Log Mean (ms) 0.6 Data Source: Data Sampling Rate (fQ: Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (fQ : 7.995 1.255 1800 1 Auto 200 Total CMR Porosity On Off Off 0.3 30 4 2 0.02 0.3 0.02 0.02 30 10 3 10 "'--", Well PEARL #1 Field South Ninilchik CMR_ECS_023LUPproœssed_anr - cryer (Project Use 0.625 77174 Expert Depth Log - B Mode 5075 to 5040 Starting Echo: EPM Processing: Logg ing Speed (ft/h): T2 Ma)(Ímum (ms): 3000 T2 Peak Search Maximum (ms): 750 SDR PHIT Exponent: SDR T2Log Exponent: Porosity Threshold (fI:3/fI:3): T2 Threshold (ms): 33 100 300 1000 3000 Medium Silt Pore/Grain Size Distribution Medium Send 20.9 14.0 0.06 7.73 1.9 0.19 18.11 6.3 Coarse Silt 21.9 0.54 38.14 18.2 Very Fine Sand Fine Sand 15.1 12.6 L. 1.72 85.17 57.2 5.07 181.70 168.9 13.07 352.63 435.5 First On From CS Arr~ 4 2 0.4 10 Coarse Sand ......2:!- 48.35 881.25 1611.7 ~ ~ Union Oil Company of California Job Number 22101 Pore/Grain Size Distribution 35 Fine Medium Coarae Very Fine Fine Medium Coarae Clay Silt Silt Silt Sand Sand Sand Sand 30 ,!: III >- 25 :iii .. 21.8 2 20.2 a. 20 .c 0 15.2 dI 1S 14.9 ,5 1: 10.S U <1/ ':-- 2 .t 0.9 """'è"'OO"'", Pore Size (urn) 0.01 0.06 0.19 0.55 1.71 5.08 U.63 4$.69 Grain Size (um) 2.99 8.31 18.29 38.20 84.81 182.08 363.21 847.08 T2 Log Mean (ma) 0.5 2.1 6.4 18.2 S6.9 169.4 454.3 1523.2 4) 5,450 - 5,520 feet Parameter Summary: Estimated Polarization Time (~: Acquisition Idle Time (5): NLimber of Echoes: Repetition Count: Regularization: Echo Spacing (u~ : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms): Number of Components: Timur/Coates PHIT Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3): T1fT2 Ratio Minimum: 0.5 T1fT2 Ratio Maximum: 3 Polarization Corr Threshold (fI3!f1:3): 0.02 Bin Porosity Cutoffs (m5): Well PEARL #1 Field South Ninilchik Data Source: Data Sampling A ate (~: Cartridge/Sonde Numbers: CMA-Plus Logging Mode: Stacked Deptt1s (~: CMA_ECS_023LUP.proœssed_cmr - cryer (Project Use 0.625 77174 Expert Depth Log - B Mode 5520 to 5450 7,995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMA Porosity On Off Off Starting Echo: EPM Processing: First On Logging Speed (ftlh): From CS Arr&iý 0.3 30 T2 MaXimum (ms): 3000 T2 Peak Search Maximum (ms): 750 4 2 0.02 SDA PHIT Exponent: SDA T2Log Exponent: 4 2 Porosity Thresho Id (ft3Ift3): T2 Threshold (ms) : 0.4 10 0,3 3 10 33 100 300 1000 3000 ~ ~ Union Oil Company of California Job Number 22101 Well PEARL #1 Field South Ninilchik Pore/Grain Size Distribution 35 Fine Medium Coarse Very Fine Fine Medium Coarse Clay Silt Silt Silt Sand Sand Sand Sand 30 I: aI >- 25 :-= 22.2 II) 2 8. 20 19.1 19.1 J: 0 .D 15 .5 13.2 1: 41 10 f 7.9 .t :~ $.1 1.2 r,_- Pore Size (urn) 0.01 0.0$ 0.20 0.5$ 1.77 5.05 13.37 44.5$ Grain Size (urn) 2.97 8.20 18.$$ 38.99 8$.95 181.39 358.31 832.30 T2 Log Mean (ms) 0.5 2.0 $.S 18.7 58.9 1$8.5 445.6 1485.3 5) 5,690 - 5,740 feet Parameter Summary: Estimated Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: RepeUtion Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms) : Number of Components: Timur/Coates PHI T Exponent: Timur/Coaæs PHI Ratio Exponent: Bound Fluid Minimum (ft3lt1:3): T1fT2 Ratio Minimum: 0.5 T1fT2 Ratio Maximum: 3 Polarization Carr Threshold (ft3!ft3): 0.02 Bin Porosity Cutoffs (ms): Data Source: Data Sampling Rate (ft): Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depltis (ft) : CMR_ECS_023LUP.proœssed_aT1r - cryer (Projed: Use 0.625 77/74 Expert Depth Log - B Mode 5740 to 5690 7.995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMR Porosity On Off Off Starting Echo: EPM Processing: First On Logging Speed (ltIh): From CS Arr<fý 0.3 30 T2Maximum (ms): 3000 T2 Peak Seard'1 Maximum (ms): 750 4 2 0.02 SDR PHIT Exponent: SDR T2Log Exponent: 4 2 Porosity Threshold (fI:3.Ift3): T2 Threshold (ms): 0.4 10 0.3 100 300 1000 3000 3 10 33 ",,-..., Union Oil Company of California Job Number 22101 6) 5,875 - 5,940 feet Parameter Summary: Estimated Polarization Time (S¡: Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us¡ : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms): Number of Components: Timur/Coates PHi T Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3): Data Source: Data Sampling R ate (~ : Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (~: T1!T2 Ratio Minimum: 0,5 T1!T2 Ratio Maximum: 3 Polarization Corr Threshold (ft3!ft3): 0,02 Bin Porosity Cutoffs (ms) : 35 Clay 30 !: iii >- 25 it:! .. 0 i 20 J: () .:J 15 ,E 'E :t 10 i u :-- Pore Size (urn) 0.01 Grain Size (urn) 2.92 T2 Log Mean (ma) 0.5 Fine Silt $.II 0.06 8.59 2.2 7,995 1,255 1800 1 Auto 200 Total CMR Porosity On Off Off 03 30 4 2 0,02 0,3 0,02 0,02 30 10 3 10 ~ Well PEARL #1 Field South Ninilchik CMR_ECS_023LUP,processed_cmr - cryer (Project Use 0625 77/74 Expert Depth Log - B Mode 5940 to 5875 Starting Echo: EPM Processing: Logging Speed (ft/h): T2 Maximum (ms): 3000 T2 Peak Search Maximum (ms): 750 SO A PHITExponent: SDR T2Log Exponent: Porosity Threshold (ft3/ft3): T2 Threshold (ms) : 33 100 300 1000 3000 Medium Silt Pore/Gra in Size Distribution Medium Send 17.7 0.19 18.44 $.II Coarae Silt 20.8 0.55 38.32 18.3 Very Fine Send Fine Send 20.3 17.8 1.75 86.21 58.2 5.10 182.46 169.9 13.56 361.88 451.9 First On From CS Arrfij 4 2 0.4 10 Coarae Send 1.2 ~"'~ 43.64 820.19 1454.6 ~. ~ Union Oil Company of California Job Number 22101 7) 6,090 - 6,130 feet Parameter Summary: Estimated Polarization Time (s): Acquisiöon Idle Time (s): Number of Echoes: Rep8Ötion Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Oespiking: T2 Speed Correction: T2 Minimum (ms) : Number of Components: Timur/Coates PHIT Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3l1t3): Well PEARL #1 Field South Ninilchik Data Source: Data Sampling R ate (~: Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (~: CMR_ECS_023LU P. processed_am - cryer (Project Use 0.625 77/74 Expert 0 epth Log - B Mode 6130to 6090 7.995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMR Porosity On Off Off Staröng Echo: EPM Processing: First On Logging Speed (ltIh): From CS ftJr&ý 0.3 30 T2 Maximum (ms): 3000 T2 Peak Search Maximum (ms): 750 4 2 0.02 SOR PHIT Exponent: SO R T2Log Exponent: 4 2 T1!T2 Ratio Minimum 0.5 T1!T2 Ratio Maximum: 3 Polarization Corr Threshold (ft3!ft3): 0.02 Bin Porosity Cutoffs (ms): Porosity Threshold (ft3Jft3): T2 Threshold (ms) : 0.4 10 0.3 3 10 33 100 300 1000 3000 Pore/Grain Size Distribution 60 Very Fine Me dium Coarae Very Fine Fine Medium Coarae $$ Clay Silt Silt Silt Sand Sand Sand Sand $0 48.9 .5 III 4$ >- :1:1 40 .. 2 3$ a. 33.0 J: 30 <> .:I 2$ .5 1: 20 4> 2 1$ l. 10 IIÌÎL8I $ 4.1 Il 1.4 0.8 0.6 0 Pore Size (um) 0.02 0.0$ 0.1$ 0.63 1.$0 4.87 16.24 $3.22 Grain Size (um) 3.18 6.7$ 1$.71 42.29 77.48 176.76 410.60 942.$1 T2 Log Meen (ma) 0.$ 1.5 5.1 21.0 50.0 162.4 $41.3 1774.1 ~ r-"\ Union Oil Company of California Job Number 22101 Well PEARL #1 Field South Ninilchik 8) 6,560 - 6,610 feet Parameter Summary: Estimated Polarization Time (s). Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms)' Number of Components: Timur/Coates PHi T Exponent: Tlmur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3): Data Source: Data Sampling Rate (fQ: Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (fQ: CMR_ECS_023LUP.processed_cmr - cryer (Project Use 0.625 77174 Expert Depth Log - B Mode 6610 to 6560 7.995 1.255 1800 1 AulD 200 0.02 0.02 30 10 Total CMR Porosity On Off Off Starting Echo: EPM Processing: First On Logging Speed (ft:lh): From CS Array 0.3 30 T2Maximum (ms): 3000 T2 Peak Search Maximum (ms): 750 4 2 0.02 SDR PHIT Exponent: SDR T2Log Exponent: 4 2 T1fTZ Ratio Minimum: 0.5 T1fT2 Ratio Maximum: 3 Poiarization Carr Threshold (ft3,fl:3): 0.02 Porosity Threshold (ft3Ift3): T2 Threshold (ms) : 0.4 10 Bin Porosity Cutoffs (ms): 0.3 3 33 100 300 1000 3000 10 Pore/Grain Size Distribution 40 Fine Medium Coarae Very Fine Fine Medium Coarae Clay Silt Silt Silt Sand Sand Sand Sand 35 .5 III 30 27.9 ;:.. :0: .. 2 25 ~ ~ 20 19.9 .D 16.1 ,5 15 1: 12.6 G b ~ 10 9.1 If 5.3 :-- 1.7 ~ Pore Siæ (um) 0.02 0.06 0.17 0.53 1.84 5.02 14.49 45.69 Grain Siæ (um) 3.64 7.90 17.22 37.33 89.54 180.42 379.05 847.00 T2 Log Mean (ma) 0.6 1.9 5.8 17.6 61.5 167.2 482.9 1523.0 ~ ~ Union Oil Company of California Job Number 22101 Well PEARL #1 Field South Ninilchik 9) 7,080 - 7,120 feet Parameter Summary: Estimaæd Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Desplking: T2 Speed Correction: T2 Minimum (ms): Number of Components: Timur/Coates PHIT Exponent: Timur/Coaæs PHI Ratio Exponent: Bound Fluid Minimum (ft3!1t3): T1!T2 Ratio Minimum: 0,5 T1!T2 Ratio Maximum: 3 Polarization Corr Threshold (fI3!ft3): 0,02 Bin Porosity Cutoffs (ms): Data Source: Data Sampling Rate (ft) : Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (ft) : CMR_ECS_023LUP, processed_am - cryer (Project Use 0,625 77114 Expert Depth Log - B Mode 1120to 1080 1,995 1,255 1800 1 Auto 200 0,02 0,02 30 10 Total CMR Porosity On Off Off Starting Echo: EPM Processing: First: On Logging Speed (ltIh): From CS fJ.1ræ¡ 0,3 30 T2 Ma>Cimum (ms): 3000 T2 Peak Seard1 Maximum (ms): 150 4 2 0,02 SDR PHIT Exponent: SD R T2Log Exponent: 4 2 Porosity Threshold (ft3Jft3): T2 Threshold (ms) : 0.4 10 0,3 3 10 33 100 300 1000 3000 Pore/Grain Size Distribution 40 Fine Me dium Coeree Very Fine Fine Medium Coeree Clay Silt Silt Silt Sand Sand Sand Sand 35 .5 11:1 30 >- 2$.$ :II:C ø 2 2S a. .c 20 18.5 () .D ,5 15 ë 12.$ Q¡ iii 2 10 9.1 8.3 .t :--- 0.8 '-'~"-'~ Pore Size (um) 0.02 0.06 0.18 0.53 1.78 5.15 13.72 48.68 Grein Size (um) 3.37 8.11 17.31 37.32 87.51 183.79 3$4.84 885.45 T2 Log Mean (me) M 2.0 5.9 17.$ 59.5 171.7 457.2 1 $22.7 Union Oil Company of California Job Number 22101 10) 7,280 - 7,320 feet Parameter Summary: Estimated Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us): Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms) : Number of Components: Timur/Coates PHI T Exponent: TimurlCoates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3) : T1rr2 Ratio Minimum: 0.5 T1rr2 Ratio Maximum: 3 Polarization Corr Threshold (ft3tft3): 0.02 Bin Porosity Cutoffs (ms): 35 Clay 30 c iii >0 ~5 1M ., 0 i ~O .c <> a3 15 .E 1: 3 10 i. 5 3.~ 0- Pore $iæ (um) O.O~ Grain $iæ (um) 3.~5 T2 Log Mean (ms) 0.5 /""""'. Fine Silt 7.$ 0.07 $.$2 2.2 Data Source: Data Sampling Rate (f1): Cartridge/Sonde Numbers: CMR-Pius Logging Mode: Stacked Depths (f1): 7.995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMR Porosity On Off Off 0.3 30 4 2 0.02 0.3 3 10 ~ Well PEARL #1 Field South Ninilchik CMR_ECS_O23LUP.proœssed_am - cryer (Project: Use 0625 77174 Expert Depth Log - B Mode 7320 to 7280 Starting Echo: EPM Processing: Logging Speed (ftIh) T2 Ma)ámum (ms): 3000 T2 Peak Search Maximum (ms) 750 SDR PHITExponent: SD R T2Log Exponent: Porosity Threshold (ft3!ft3): T2 Threshold (ms) : 33 100 300 1000 3000 Medium Silt Coarse Silt Pore/Grain Size Distribution Medium Sand 1$.1 0.1$ 1$.53 6.5 0.55 3$.46 1$.4 Very Fine Sand Fine Sand 22.9 ~ 1.&1 $$.5~ 60.5 5.0& 1$1.4$ 168.6 1~.S$ 362.00 452.2 First On From CS Array 4 2 0.4 10 Coarse Sand 1.6 IIIIIIII 45.24 $41.1~ 1507.$ - Union Oil Company of California Job Number 22101 11) 7,555 - 7,590 feet Parameter Summary: Estimated Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Corred:ion: T2 Minimum (ms): Number of Components: Timur/Coates PHIT Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3lft3) : T1rr2 Ratio Minimum: 0.5 T1rr2 Ratio Maximum: 3 Polarization Carr Threshold (ft3!ft3): 0.02 Bin Porosity Cutoffs (ms): 40 35 Clay c ii5 30 >- :101 ., 0 25 8. -S 20 .rr .: 15 1: 41 f 10 .t 5 2.7 0- Pore Size (um) 0.02 Grain Size (um) 3.24 T2 Log Mean (msl 0.5 ~ Fine Silt u . 0.06 8.41 2.1 Data Source: Data Sampling Rate (ft): Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (ft): 7.995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMR Porosity On Off Off 0.3 30 4 2 0.02 0.3 3 10 ~ CMR_ECS_023LUP.processed_am - cryer 0.625 77174 Expert Depth Log - B Mode 7590 to 7555 Starting Echo: EPM Processing: Logging Speed (It/h): T2 MaXimum (ms): 3000 T2 Peak Search Maximum (ms): 750 SDA PHITExponent: SD A T2Log Exponent: Porosity Threshold (fI:3Ift3): T2 Threshold (ms): 33 100 300 1000 3000 Medium Silt Coarse Silt Pore/Grain Size Distribution Very Fine send Fine send Me dium send 27.7 0.20 1$.62 6.5 0.56 38.$$ 18.6 20.5 15.5 1.67 83.$$ 55.$ 14.1$ 373.65 473.1 4.&8 179.44 165.9 Well PEARL #1 Field South Ninilchik (Projed: Use Firs: On From CS þ.Jr<1ý 4 2 0.4 10 Coarse send 1.2 """'-~ 45.$7 $50.66 1532.4 ~. /"'"'.. Union Oil Company of California Job Number 22101 12) 7,670 - 7,730 feet Parameter Summary: EstimatEd Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count: Reguiarization: Echo Spacing (us). Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Correction: T2 Minimum (ms) : Number of Components: Timur/CoatEs PHI T Exponent: Timur/CoatEs PHI Ratio Exponent: Bound Fluid Minimum (ft3!1t3): Well PEARL #1 Field South Ninilchik Data Source: Data Sampling Rate (fQ: Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (fQ: CMR_ECS_023LUP.processed_cmr - cryer (Project Use 0.626 77/74 Expert Depth Log - B Mode 7730 to 7670 7.996 1.266 1800 1 Auto 200 0.02 0.02 30 10 Toæl CMR Porosity On Off Off Starting Echo: EPM Processing: First On Logging Speed (ftIh): From CS f'.!ray 0.3 30 T2Maximum (ms): 3000 T2 Peak Search Maximum (ms): 760 4 2 0.02 SDR PHIT Exponent: SD R T2Log Exponent: 4 2 T1!T2 Ratio Minimum: 0.6 T1!T2 Ratio Maximum: 3 Polarization Corr Threshold (fI3!ft3): 0.02 Pore/Grain Size Distribution 3$ Fine Medium Coarse Very Fine Fine Medium Coarse Clay Silt Silt Silt sand sand sand sand 30 .5 D:I ::- 2$ 23.7 .'fI1! III 21.1 2 a. 20 J:. .. .:J 1$ 14.1 .5 12.8 1: 11.3 .. 10 8.9 f .t :--- 1.1 ~ Pore Size (um) 0.02 0.06 0.19 U4 1.76 5.14 13.96 48.69 GrainSia (um) 3.29 8.20 18.07 37.86 86.54 183.61 369.26 88$.$8 T2 Log Mean (ms) U 2.0 6.2 18.0 58.5 171.5 465.2 1623.0 Bin Porosity Cutoffs (ms) . Porosity Threshold (ft3IfI3): T2 Threshold (ms) : 0.4 10 0.3 3 33 100 30.0 10.00 30.0.0 10. ~ Union Oil Company of California Job Number 22101 13) 7,795 - 7,835 feet Parameter Summary: Estimated Polarization Time (s): Acquisition Idle Time (s): Number of Echoes: Repetition Count: Regularization: Echo Spacing (us) : Porosity Algorithm: Polarization Correction: Raw Echo Despiking: T2 Speed Corredion: T2 Minimum (ms): Number of Components: Timur/Coates PHIT Exponent: Timur/Coates PHI Ratio Exponent: Bound Fluid Minimum (ft3/ft3) : T1{f2 Ratio Minimum: 0.5 T1{f2 Ratio Maximum: 3 Polarization Corr Threshold (ft3!ft3): 0.02 Bin Porosity Cutoffs (ms): 40 Clay 35 c: iii 30 >- :1;1 loa i 25 -ä 20 .II .5 15 1: ~ ~ 10 It 5.8 :- Pore Size (um) 0.01 Grain Size (um) 2.82 T2 Log Mean (ma) 0.4 Fine Silt 4.6 0.06 7.98 1.9 Data Source: Data Sampling Rate (f!): Cartridge/Sonde Numbers: CMR-Plus Logging Mode: Stacked Depths (f!) : 7.995 1.255 1800 1 Auto 200 0.02 0.02 30 10 Total CMR Porosity On Off Off 0.3 30 4 2 0.02 0.3 3 10 ~ Well PEARL #1 Field South Ninilchik CMR_ECS_023LUP.proœssed_anr - cryer (Projed Use 0.625 77174 Expert Depth Log - B Mode 7835 to 7795 Starting Echo: EPM Processing: Firsi: On Logging Speed (ltIh): From CS Arrcr.¡ T2 Maximum (ms): 3000 T2 Peak Search Maximum (ms): 750 SDR PHIT Exponent: SD R T2Log Exponent: 4 2 Porosity Threshold (fI:3IfI2): T2 Threshold (ms): 0.4 10 33 100 300 1000 3000 Medium Silt Coarae Silt Pore/Grain Size Distribution Medium Sand 16.5 0.20 19.22 6.8 0.56 39.09 18.8 Very Fine Sand Fine Sand 25.6 18.6 1.79 87.83 59.8 5.14 183.45 171.2 13.8$ 367.43 461.9 Coarae Sand 2.6 l1li1 4S.38 842.96 1512.$ RE: Scheduled BOP Test H&R #9 '-- ~ Subject: RE: Scheduled BOP Test H&R #9 ì F\ -::ì 0 l \ Date: Sun, 10 Mar 200212:02:17 -0800 <::::t-V cr-- \i From: "Fahrlender, Harold F -Contract" <fahrlenderh@unocal.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us>, "Fahrlender, Harold F -Contract" <fahrlenderh@unocal.com> CC: "Stock, Gary W -Contract" <stockg@unocal.com>, "Mosley, Jim I" <mosleyj@unocal.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Mr. Maunder, As a follow up to the variance in testing, the casing hanger pack off was tested to 5000 psi and the casing was tested to 3000 psi after the clean out trip was made. The packer and tubing have been ran and set without problems and the packer was tested to 1500 psi for 15 minutes. The tubing hanger tested to 5000 psi and a BPV has been installed. Well has not been perforated, Thank you, Harold Fahrlender UNOCAL Drilling Foreman (Contract) 907-776-6616 (6614) -----Original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, March 01,20024:21 f-'M To: Fahrlender, Harold F -Contract Cc: Stock, Gary W -Contract; Mosley, Jim I; AOGCC North Slope Office Subject: Re: Scheduled BOP Test H&R #9 Harold, Thanks for the message. What you have described is acceptable, with the provision that if the planned isolation is not achieved that testing would proceed in advance of any continuing work. Good luck. Tom Maunder, PE AOGCC "Fahrlender, Harold F -Contract" wrote: > Mr. Maunder, > > As per our phone conversation of this afternoon 12:35 03-07-02: > > We are presently running 7" production casing on the Pearl #1 well and > should be on bottom later today, at which point we will cement the casing in > place. We will not be perferating or completing the well with the drilling > rig over the hole. We are however due a Weekly BOP Test tonight and will > be over the well a couple of more days as we clean out, lay down drill pipe, > run a packer and string of tubing. As the well bore will be secure we would > request fore-going the test as long as we pressure test the casing after > cement is in place and the annulus pack off is in place. If at any time > there are problems or pressure integrity can not be maintain we will reveret > to the regular scheduled test proceedures. > > Thank you, 1 of2 3/12/029:27 AM ~~ UNOCAL8 ELEVATION: 222.5 Feet ACTUAL RKB = 17.37 1 - - 2 3 4 5 ~ = .iIII mil = 1111111111 I . PBTD = 6,945' ELM TD = 8,000' Vertical PEARL # 1 ,-- SOUTH NINILCJ Well PEARL # 1 Actual CompletioJ 6 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID 13-3/8" 61 K-55 Butt 12.515 .. 9-5/8" 47 L-80 Butt 8.681 7" 26 L-80 Butt Mod 6.276 7" 29 L-80 Butt TKC 6.184 Tubing 3-1/2" 9.2 L-80 Butt SC 2.992 3/8" .25 416 SS Continuous .25 JEWELRY DETAIL NO. Depth ID OD Item I 17.37' 2.992 11" Tubing Hanger, 3-1/2" 2 1968' 2.990 5.437 Chemical Injection Mandrel 3 3706' 2.990 SAB 40-32 Baker Packer 4 3,754' 2.661 "XN" Nipple 5 3788' 2.990 Shear Out Ball Sub wI W/L Er 6 TBD Methanol Injection Line Perforations Date Zone Top BTM Length Comments 3/19/02 7800 7798' 7836' 36' 2", PI, 6spf, ( 3/25/02 7300 7289' 7319' 30' 2", PI, 6spf, 3/28/02 5700 5694' 5734' 40' 2", PI, 6spf, 3/29/02 4000 4008' 4043' 35' 2", PI, 6spf, .. Perfs 5694' -5734' Toe 6954' Perfs 7289'-7319' Plug at 7755', TOe = 7730' Perfs 7799'-7835' DRAWN BY: J.I.M. REV ."""""", ,-.,." - . a.Od.~Oll ~, UNOCAL8 UNOCAL ALASKA RESOURCES, INC. PEARL #1 NINILCHIK Section 24, T 01 S, R 14 W N i n i Ichi k, Alaska ~ March 5, 2002 Andrew Buchanan - Senior Logging Geologist Doug Ottke - Logging Geologist /~ ~ EPOCH ~, ,--., UNOCAL8 PEARL #1 ,~ UNOCAL8 Unocal Alaska Resources, Inc. Pearl #1 Ninilchik Field Ninilchik, Alaska TABLE OF CONTENTS WELL RESUME... .... ......... ................. ..... ...... ............. ..... .... ......... ............. ............. .... ...........2 LITHOLOGY SUMMARY ......................................................................................................3 .~ CAlLY CHRONOLOGY ......................................................................................................22 SHOW REPORTS. .... .......................... .... ..... ................. ....... ............. ...... .... ..... .... ..... .... ...... 24 MUD RECORD ..... ............ ............... ................. ......... ........... .... .............. .... ....... ......... .... .... 34 SURVEY RECORD .............................................................................................................35 BIT RECORD ...................................................................................................................... 37 MORNING REPORTS................................. ............. .................... ..................... .APPENDIX 1 WELL LOGS......................................................................................................APPENDIX 2 .~ U EPOCH 1 ~ OPERATOR: WELL NAME: FIELD: REGION: LOCATION: BOROUGH: STATE: ELEVATION: AFE NUMBER: API NUMBER: SPUD DATE: TOTAL DEPTH: r' DRILL OUT SURFACE CORE INTERVAL: OPERATOR REPRESENTATIVES: COMPANY GEOLOGIST: CONTRACTOR: DRILLING RIG: Toolpusher: MUDLOGGING COMPANY: Logging Geologists: MUD COMPANY: Mud Engineers: MWD COMPANY: CEMENT COMPANY: WIRELINE COMPANY: ~ .~ GL: KB: .."-""'. UNOCAL8 PEARL #1 WELL RESUME UNOCAL ALASKA RESOURCES INC. PEARL #1 NINILCHIK NINILCHIK SEC. 24, Township 01 S, Range 14 W KENAI BOROUGH ALASKA 225.80' 242.40' 153059 50-133-20509-00 February 17, 20021800 hrs 8000.0' md 03/05/2002 0030hrs 2/22/02 1530 7257.0'-7341.5' Jim Benson / Harold Fahrlender Mark Lynch H & R Kuukpik Drilling H&R#9 David Lancaster / Jerry Otto EPOCH WELL SERVICES, INC. Andrew Buchanan, Doug Ottke MI Forrest Slater / Jim Brown ANADRILL / SCHLUMBERGER DOWELL / SCHLUMBERGER SCHLUMBERGER U EPOCH 2 ~.. .~ UNOCAL8 PEARL #1 ~. LITHOLOGY SUMMARY 300' - 380' Sand/Sandstone = medium light gray to light gray occasionally greenish gray in overall color with individual grains white, black, green, orange and translucent; general quartz framework with secondary potassium feldspar and lithics; fine grading to medium grain size with scattered bit impacted pebbles; moderate sorting; subrounded to rounded angularity; moderate to high sphericity; mechanical abrasion apparent on larger grains; estimated 60% quartz, 30% assorted metalithics, 10% chert content within occasionally well indurated clay matrix. 380' - 440' Tuffaceous Siltstone = medium light gray to very light gray in color; stiff consistency; sectile occasionally malleable tenacity; irregular, earthy, occasionally hackly fracture; massive cuttings habit; dull, earthy luster; clayey grading to silty or gritty texture; massive structure with laminations including carbonaceous material in the bedding planes in more silty samples; slight reaction to HC!. 440' - 520' Conalomeratic Sand = pale yellowish brown in overall color with individual grains varying in color from white to black with very pale orange, grayish orange, grayish orange pink, greenish gray to grayish green, and translucent; mostly quartzose framework with scattered lithics; coarse to very coarse grain size with pebble sized grains; poor to very poorly sorted; subangular to subrounded angularity; moderate to low sphericity; bit impacted mechanical abrasion surface features observed; 70% quartz, 30% metalithic make-up with abundant mica flakes. ,r--, 520' - 580' Sand = medium gray to medium dark gray overall appearance with individual grains white, black, translucent, grayish green and moderate red in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity; bit impacted mechanical abrasions present; some grain supported lithified sandstone present. 580' - 635' Sand = medium gray to medium dark gray overall appearance with individual grains white, black, translucent, grayish green and moderate red in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity; bit impacted mechanical abrasions present; grain supported. 635' - 715' Sand/Sandstone = medium light gray to light gray occasionally greenish gray in overall color with individual grains white, black, green orange and translucent; general quartz framework with secondary potassium feldspar and lithics; fine grading to medium grain size with scattered bit impacted pebbles; moderate sorting; subrounded to rounded angularity; moderate to high sphericity; mechanical abrasion apparent on larger grains; estimated 60% quartz, 30% assorted metalithics, 10% chert content within occasionally well indurated clay matrix. 715' - 775' Tuffaceous Siltstone = medium light gray to very light gray in color; stiff consistency; sectile occasionally malleable tenacity; irregular, earthy, occasionally hackly fracture; massive cuttings habit; dull, earthy luster; clayey grading to silty or gritty texture; massive structure with laminations including carbonaceous material in the bedding planes in more silty samples; slight reaction to HC!. ~ U EPOCH 3 .~. """'. UNOCAL8 PEARL #1 r---.. 775' - 830' Sand = medium gray to medium dark gray overall appearance with individual grains white, black, translucent, grayish green and moderate red in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity; bit impacted mechanical abrasions present; grain supported. 830' - 875' Tuffaceous Siltstone = medium light gray to very light gray in color; stiff consistency; sectile occasionally malleable tenacity; irregular, earthy, occasionally hackly fracture; massive cuttings habit; dull, earthy luster; clayey grading to silty or gritty texture; massive structure. 875' - 930' Sand = medium gray to medium dark gray overall appearance with individual grains white, black, translucent, grayish green and moderate red in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity; bit impacted mechanical abrasions present. 930' - 985' Sand = medium gray to medium dark gray overall appearance with individual grains white, black, translucent, grayish green and moderate red in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity; bit impacted mechanical abrasions present; grain supported. 985' - 1025' Coal = black occasionally dark reddish brown where grading to carbonaceous shale in color, tough to brittle tenacity; block to irregular fracture; resinous, greasy luster; smooth texture; laminated, thinly bedded structure; no visible gas bleeding. .-----... 1025' -1070' Tuffaceous Claystone = medium light gray to very light gray in color; stiff consistency; sectile occasionally malleable tenacity; irregular, earthy, occasionally hackly fracture; massive cuttings habit; dull, earthy luster; clayey grading to silty or gritty texture; massive structure. 1070' -1110' Sand = medium gray to medium light gray appearance with individual grains white, black, translucent in color; quartz, lithic framework; medium to coarse grain size; moderately to poorly sorted; subangular to subrounded, generally moderate to high sphericity. 1110' -1170' Tuffaceous Siltstone = medium gray to medium light gray in color with black and dark reddish brown flakes of carbonaceous material within gray matrix; malleable, occasionally pulverulent tenacity; irregular fracture; massive cuttings habit; greasy to dull occasionally earthy luster; silty, gritty grading to clayey texture; massive structure with occasional laminations. 1170' -1215' Tuffaceous Claystone = medium light gray to very light gray in color; stiff consistency; sectile occasionally malleable tenacity; irregular, earthy, occasionally hackly fracture; massive cuttings habit; dull, earthy luster; clayey grading to silty or gritty texture; massive structure. 1215' -1265' Sand = light gray overall; medium upper to very coarse; subround overall; moderately sphericity; moderate to well sorted; composed of 50% quartz 50% igneous and metamorphic lithics; unconsolidated; common to abundant mica (biotite, muscovite and chlorite); common chert; estimate good intergranular porosity; no visible oil indicators. ----.. fj EPOCH 4 ,-.... . ~ UNOCAL8 PEARL #1 ~ 1265' -1305' Clay = light to medium gray; stiff; brittle to malleable; irregular to sub blocky fracture; massive cuttings; dull earthy to occasional sparkly luster; smooth to gritty texture; common visible mica and glass shards; grades to silt in part; occasional visible ash. 1305' -1355' Sand = light gray overall; medium upper to very coarse; subround overall; moderately sphericity; moderate to well sorted; composed of 50% quartz 50% igneous and metamorphic lithics; unconsolidated; common to abundant mica (biotite, muscovite and chlorite); common chert; estimate good intergranular porosity; no visible oil indicators. 1355' -1405' Sand = light gray to medium gray; fine to very coarse; predominantly subround; moderate sphericity; moderate sorting with local poor sorting; unconsolidated; composed of 40% to 60% quartz; 40% to 60% igneous and metamorphic lithics; occasional laminations of silt and clay; estimate good to excellent intergranular porosity with no visible oil indicators. 1405' - 1435' Carbonaceous Clay = medium brown to brownish black; firm to hard; irregular planar fracture; flaky to tabular cuttings; earthy and resinous luster; smooth to gritty texture. 1435' -1475' Clav = light to medium gray; stiff; brittle to malleable; irregular to sub blocky fracture; massive cuttings; dull earthy to occasional sparkly luster; smooth to gritty texture; common visible mica and glass shards; grades to silt in part; occasional visible ash, .~ 1475' -1510' Clay = light gray; adhesive; hydrofissile; mushy to pasty; occasional crumbly; massive amorphous cuttings; dull earthy to sparkly luster; gritty texture; abundant shards; common laminations of ash; grades to silt in part; occasional carbonaceous material. 1510' -1550' Tuffaceous Ash; white to very light brownish yellow; firm to stiff; brittle; irregular to blocky fracture; predominantly equant cuttings; waxy to sparkly luster; smooth to occasional gritty; common visible shards; predominantly occurs as thin laminations in clays; very hydrofissile. 1550' -1585' Coal = black to very dark brown; hard; occasionally brittle; irregular and planar fracture; elongate to wedge like cuttings; resinous luster; smooth text; common interbeds of clay; trace visible gas bleed. 1585' -1625' Siltstone = light gray to light brownish gray; firm to hard; predominantly quartzose with common clay, ash and occasional carbonaceous material; occasionally appears welded; irregular fracture and cuttings; earthy to waxy to sparkly luster; grades to clay and sandstone in part. 1625' - 1660' Clay = light gray; adhesive; hydrofissile; mushy to pasty; occasional crumbly; massive amorphous cuttings; dull earthy to sparkly luster; gritty texture; common shards; common laminations of ash; grades to silt in part; trace carbonaceous material. 1660' - 1705' Sand = medium gray; very fine to coarse; poor to moderate sorting; subangular to subround; low to moderate sphericity; composed of 30% quartz, 70% igneous and metamorphic lithic fragments; predominantly mafic igneous rocks with occasional mica visible; unconsolidated; occasionally grades to siltstone; estimated poor intergranular porosity. ~. n EPOCH 5 ",........., ~ UNOCALe PEARL #1 ~ 1705' - 1740' Clay = very light gray; adhesive; mushy; malleable; irregular to blocky fracture; predominantly amorphous cuttings; dull earthy and sparkly luster; smooth to silty texture; common visible shards; trace laminations of carbonaceous material. 1740' -1780' Siltstone = light gray to light brownish gray; firm to hard; predominantly quartzose with common clay, ash and occasional carbonaceous material; occasionally appears welded; irregular fracture and cuttings; earthy to waxy to sparkly luster; grades to clay and sandstone in part. Note: drill to surface casing point at 1800'. Circulate bottoms up, pump sweep and circulate hole clean. Pull out of the hole to run 9 5/8" casing. Casing landed at 1793'. Drilled out cement 02/22/02 1530 hrs. 1815' -1860' Claystone = light to very light greenish gray; adhesive; lightly cohesive; clumpy to mushy; malleable and crumbly in part; irregular fracture; massive cuttings; dull earthy to matte luster; smooth with occasional gritty texture; occasional visible shards; occasional laminations of carbonaceous clay and tuff ash. 1860' - 1905' Claystone = light to very light greenish gray; adhesive; lightly cohesive; clumpy to mushy; malleable and crumbly in part; irregular fracture; massive cuttings; dull earthy to matte luster; smooth with occasional gritty texture; occasional visible shards; occasional laminations of carbonaceous clay and tuff ash. ~ 1905' -1935' Carbonaceous Shale = brownish gray to brownish black; firm to hard; irregular planar fracture; flaky to tabular cuttings; earthy and resinous luster; smooth to gritty texture. 1935' - 1975' Coal = black occasionally dark reddish brown where grading to carbonaceous shale in color; tough to brittle tenacity; block to irregular fracture; resinous, greasy luster; smooth texture; laminated, thinly bedded structure; no visible gas bleeding. 1975' - 2010' Claystone = medium gray to medium light gray; mushy to slimy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; hydrophilic. 2010' - 2050' Sand = individual grains black, clear, translucent; quartz framework; medium to fine grain size; fair to well sorted; subrounded to subangular; moderate sphericity; bit impacted mechanical abrasion; 90% quartz, 10% assorted metalithics within clay matrix. 2050' - 2085' Carbonaceous Shale = grayish black to dusky brown, occasionally moderate brown; crumbly to crunchy tenacity; irregular fracture; greasy luster; gritty occasionally matte texture; fissile grading to massive structure. 2085' - 2125' Coal = black occasionally dark reddish brown where grading to carbonaceous shale in color; tough to brittle tenacity; block to irregular fracture; resinous, greasy luster; smooth texture; laminated, thinly bedded structure; no visible gas bleeding. ~ [:I EPOCH 6 ~ :~ UNOCAL8 PEARL #1 ."'--' 2125' . 2170' Claystone = medium gray to medium light gray; mushy to slimy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; commonly grading to siltstone, with carbonaceous material present to abundant; no reaction to HC!. 2170' - 2205' Siltstone = medium gray to medium light gray; mushy consistency; pulverulent, occasionally malleable tenacity; irregular, fracture; dull, earthy luster; silty, gritty texture grading to clayey; massive structure. 2205' - 2245' Claystone = medium gray to medium light gray; mushy to slimy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; commonly grading to siltstone, with carbonaceous material present. 2245' - 2295' Sand/Sandstone = overall dark gray to grayish black in color with individual grains black, translucent, and clear; quartz framework; medium to coarse grained; moderately sorted; subangular to subrounded; moderate sphericity; grain supported with 80% quartz, 20% metalithics; sandstone very well indurated. 2295' - 2330' Coal = black occasionally dark reddish brown where grading to carbonaceous shale in color; tough to brittle tenacity; block to irregular fracture; resinous, greasy luster; smooth texture; laminated, thinly bedded structure; ~ 2330' - 2365' Carbonaceous Shale = grayish black to dusky brown, occasionally moderate brown; crumbly to crunchy tenacity; irregular fracture; greasy luster; gritty occasionally matte texture; fissile; effervesces in HC!. 2365' . 2420' Claystone = medium gray to medium light gray; mushy to slimy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; commonly grading to siltstone; carbonaceous material present. 2420' - 2455' Siltstone = medium gray to medium light gray; mushy consistency; pulverulent, occasionally malleable tenacity; irregular, fracture; dull, earthy luster; silty, gritty texture grading to clayey; massive structure. 2455' - 2500' Sand/Sandstone = overall dark gray to grayish black in color with individual grains black, translucent, and clear; quartz framework; medium to coarse grained; moderately sorted; subangular to subrounded; moderate sphericity; grain supported with 80% quartz, 20% metalithics. 2500' - 2545' Claystone = medium gray to medium light gray; cohesive and adhesive; mushy to slimy consistency; malleable to pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; commonly grading to siltstone; carbonaceous material present. 2545' - 2580' Coal = black occasionally brownish black to grayish black; brittle to crunchy tenacity; splintery, hackly fracture; greasy luster; matte texture; fissile structure; no visible gas bleeding. r---. ~ EPOCH 7 ~ ~ UNOCAL8 PEARL #1 ~', 2580' - 2615' Siltstone = medium gray to medium light gray; mushy consistency; pulverulent, occasionally malleable tenacity; irregular, fracture; dull, earthy luster; silty, gritty texture grading to clayey; massive structure. 2615' - 2650' Claystone = medium gray to medium light gray; mushy to slimy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; massive structure. 2650' - 2690' Sand = medium light gray to medium gray; quartz framework; medium to fine grained; moderately sorted; subrounded to rounded; moderate sphericity; 90% quartz, 10% metalithics, flakes of carbonaceous material common; matrix supported. 2690' - 2720' Carbonaceous Shale = grayish black to dusky brown, occasionally moderate brown; crumbly to crunchy tenacity; irregular fracture; greasy luster; gritty occasionally matte texture; fissile. 2720' - 2755' Claystone = medium gray to medium light gray; adhesive; mushy consistency; pulverulent tenacity; irregular fracture; dull to earthy luster; smooth, clayey texture grading to silty and gritty; massive structure, 2755' - 2790' Siltstone = medium gray to medium light gray; mushy consistency; pulverulent, occasionally malleable tenacity; irregular, fracture; dull, earthy luster; silty, gritty texture grading to clayey; massive structure. ~ 2790' - 2835' Clay = very light gray to light greenish gray; cohesive and adhesive; very hydrofissile; pasty to slightly stiff; malleable to occasional crumbly; irregular to sub planar fracture; massive to sub tabular cuttings; dull earthy to sparkly luster; common laminations of ash and abundant visible shards; occasional very thin laminations of carbonaceous material commonly grades to siltstone. 2835' - 2885' Siltstone = light gray to light brownish gray; crumbly to malleable; irregular to earthy fracture; massive to occasional sub tabular cuttings; dull earthy to matte luster with common sparkly luster; gritty to abrasive texture; commonly thinly interbedded with grading to clay; occasional grades to very fine sandstone; common laminations of ash and carbonaceous material; abundant visible glass shards. 2885' - 2930' Clay = very light gray to light greenish gray; cohesive and adhesive; very hydrofissile; pasty to slightly stiff; malleable to occasional crumbly; irregular to sub planar fracture; massive to sub tabular cuttings; dull earthy to sparkly luster; common laminations of ash and abundant visible shards; occasional very thin laminations of carbonaceous material commonly grades to siltstone. 2930' - 2970' Sand = light to medium gray overall; predominantly very fine to fine with common medium grains; subround to subangular; moderately to well sorted; moderately to high sphericity; 40% to 60% quartz, 40%-60% igneous and metamorphic lithics; unconsolidated with rare consolidated laminations; grades to siltstone; finely interbedded with silt and clay; no visible oil shows. --- (J EPOCH 8 ~ ,~ UNOCAL8 PEARL #1 .,-, 2970' - 3000' Limestone = medium gray; cryptocrystalline; mudstone; very hard; no visible particles; very argillaceous; occasional carbonaceous material inclusions; grades to very calcareous clay/shale; no visible porosity. 3000' - 3050' Sand = light to medium gray; very fine to fine with rare medium grains; moderate to well sorted; subround overall; moderately sphericity; 50%-60% quartz, 40%-50% igneous and metamorphic lithic; predominantly unconsolidated with occasional consolidated very fine sand grading to siltstone; thinly interbedded with silt and clay; commonly grades to siltstone; occasional laminations of ash; assume abundant clay ash matrix; estimated very poor to poor intergranular porosity, no shows. 3050' - 3095' Clay = very light gray to light greenish gray; cohesive and adhesive; very hydrofissile; pasty to slightly stiff; malleable to occasional crumbly; irregular to sub planar fracture; massive to sub tabular cuttings; dull earthy to sparkly luster; common laminations of ash and abundant visible shards; occasional very thin laminations of carbonaceous material commonly grades to siltstone. 3095' - 3130' Coal = black to very dark brown; very hard; brittle; irregular to conchoidal fracture; blocky to wedge like cuttings; vitreous to resinous luster; smooth texture; occasional very argillaceous; grades to carbonaceous clay in part; common to abundant visible bleeding gas. 3130' - 3165' Clay = very light gray to light gray; mushy to pasty; moderately cohesive; adhesive; malleable to sectile; occurs as amorphous lumps; very hydrofissile; matte to occasional sparkly luster; smooth to gritty texture; grades to siltstone; abundant tuff ash; abundant glass shards. ~ 3165' - 3210' Sandstone = medium light gray to medium gray with individual grains within the matrix black, translucent, clear, white; fine grained grading to very fine quartz framework; well sorted; well rounded; high sphericity; laminated, fissile structure grading to siltstone with abundant carbonaceous stringers. 3210' - 3255' Siltstone = medium light gray to yellowish gray; very cohesive to slightly adhesive; stiff consistency; malleable to sectile occasional tough tenacity; irregular fracture; greasy to dull luster; silty gritty texture grading to clayey and granular; massive occasional finely laminated with common carbonaceous stringers. 3255' - 3300' Coal = black to brownish black; tough to brittle tenacity; irregular to splintery, occasional conchoidal fracture; block cuttings habit; vitreous to resinous occasional dull luster; smooth to matte texture; grading to carbonaceous shale; occasional argillaceous; no visible bleeding. 3300' - 3335' Claystone = medium light gray to light gray; moderately adhesive, hydrofissile; mushy to pasty; malleable to pulverulent; irregular fracture; dull occasional sparkling luster; clayey grading to gritty texture; abundant glass shards. 3335' - 3380' Siltstone = medium light gray to yellowish gray; very cohesive to slightly adhesive; stiff consistency; malleable to sectile occasional tough tenacity; irregular fracture; greasy to dull luster; silty gritty texture grading to clayey and granular; massive occasional finely laminated with common carbonaceous stringers. ~ U EPOCH 9 ~ UNOCAL8 PEARL #1 ~ 3380' - 3415' Claystone = medium light gray to light gray; moderately adhesive, hydrofissile; mushy to pasty; malleable to pulverulent; irregular fracture; dull occasional sparkling luster; clayey grading to gritty texture; abundant glass shards. ~ 3415' - 3455' Coal = black to brownish black; tough to brittle tenacity; irregular to splintery, occasional conchoidal fracture; block cuttings habit; vitreous to resinous occasional dull luster; smooth to matte texture; grading to carbonaceous shale; no visible gas bleeding. 3455' - 3495' Sand = medium light gray to medium gray; quartz framework; medium to fine grained; moderately sorted; subrounded to rounded; moderate sphericity; 90% quartz, 10% metalithics, flakes of carbonaceous material common; matrix supported. 3495' - 3530' Claystone = medium light gray to light gray; moderately adhesive, hydrofissile; mushy to pasty; malleable to pulverulent; irregular fracture; dull occasional sparkling luster; clayey grading to gritty texture; abundant glass shards, 3530' - 3570' Coal = black to brownish black; tough to brittle tenacity; irregular to splintery, occasional conchoidal fracture; block cuttings habit; vitreous to resinous occasional dull luster; smooth to matte texture; grading to carbonaceous shale; no visible gas bleeding. 3570' - 3620' Siltstone = medium light gray to medium gray; tough, brittle to sectile tenacity; irregular to slightly conchoidal fracture; flaky occasional platy cuttings habit; greasy, resinous occasional frosted luster; silty, gritty grading to granular texture; massive to very thinly laminated structure; occasional very well indurated; reacts to HCI, moderately calcareous. r--- 3620' - 3660' Claystone = light gray to very light gray; moderately cohesive to very adhesive; curdy to mushy; malleable occasional pulverulent; dull to sparkling luster; smooth, clayey grading to gritty texture; abundant tuff ash; moderately sand grains and carbonaceous material suspended in matrix. 3660' - 3705' Sand = light gray to medium gray with individual grains translucent, clear, black; predominantly very fine to fine grained; subround to subangular; moderately to well sorted; moderately to high sphericity; 70% quartz, 30% igneous and metalithics; unconsolidated within clay matrix; common grading to silt sized grains. 3705' - 3740' Coal = black to brownish black; tough to brittle tenacity; irregular to splintery, occasional conchoidal fracture; block cuttings habit; vitreous to resinous occasional dull luster; smooth to matte texture; grading to carbonaceous shale. 3740' - 3790' Claystone = light gray to very light gray; moderately cohesive to very adhesive; curdy to mushy; malleable occasional pulverulent; dull to sparkling luster; smooth, clayey grading to gritty texture; abundant tuff ash, sand, and carbonaceous material. 3790' - 3820' Sand = light gray to medium gray with individual grains translucent, clear, black; predominantly very fine to fine grained; subround to subangular; moderately to well sorted; moderately to high sphericity; unconsolidated; common grades to silt. ,---- ~ EPOCH 10 ~ ~. UNOCAL8 PEARL #1 ~. 3820' - 3870' Sand/Sandstone = very light gray overall; very fine to fine with occasional medium grains; subround to round; moderately to in part well sorted; composed of 70% quartz, 30% igneous and metamorphic lithics; commonly grades to siltstone; finely interbedded with clay and siltstone; unconsolidated and matrix supported consolidated cuttings; common laminations of tuff ash and clay; occasional iron staining; common carbonaceous material; estimated very poor intergranular porosity; no shows. 3870' - 3905' ~ = light gray to light brownish gray; cohesive and adhesive; hydrofissile; mushy; malleable to sectile; occurs as amorphous clumps; matte to occasional sparkly luster; smooth to gritty texture; occasional visible laminations of silt and ash; common laminations showing abundant carbonaceous material. 3905' - 3935' Coal = black to brownish black; tough to brittle; irregular to splintery, occasional conchoidal fracture; blocky cuttings; vitreous to resinous occasional dull luster; smooth to matte texture; grading to carbonaceous shale. 3935' - 3975' Sand/Sandstone = light gray tQ whitish gray; very fine to medium grains; subround to round with occasional subangular; moderately sorting; moderately sphericity; 70% quartz, 30% igneous and metamorphic lithics; unconsolidated and matrix supported consolidated cuttings; occasional grades to and interbedded with siltstone; porosity infilled with clay and ash in part; estimated very poor to good intergranutar porosity; no shows. ~ 3975' - 4010' Clay = light gray to light brownish gray; cohesive and adhesive; hydrofissile; mushy; malleable to sectile; occurs as amorphous clumps; matte to occasional sparkly luster; smooth to gritty texture; occasional visible laminations of silt and ash; common laminations showing abundant carbonaceous material. 4010' - 4060' Sand/Sandstone = light gray to whitish gray overall; very fine to medium with occasional coarse grains; moderately sorting; subangular to subround; moderately to low sphericity; 80% quartz 20% lithics with common to abundant mica, trace glauconite; unconsolidated and consolidated; consolidated: 50% grain supported 50% matrix supported; common clay and ash infilling porosity; estimated predominantly very poor to poor with common fair to good intergranular porosity; no visible oil indicators. 4060' - 4100' Siltstone = light gray to whitish gray; soft to firm; occurs as well rounded cuttings; no visible fracture; earthy with common sparkly luster; gritty to abrasive texture; occasional visible gradation from clay to silt to very fine sand; predominantly quartzose; abundant ashy laminations. 4100' - 4140' Clay = light gray to grayish brown; cohesive and adhesive; hydrofissile; mushy to clumpy consistency; malleable to crumbly; massive well rounded cuttings; earthy dull luster; smooth to gritty texture; occasional visible gradational contact with siltstone; common carbonaceous material; common ash. (1 EPOCH 11 ~ ~ UNOCALe PEARL #1 r-----, 4140' .4190' Sand = light gray overall; very fine to medium with rare coarse grains; moderately sorting; subangular to subround; moderately to low sphericity; 70% quartz, 30% lithics; predominantly unconsolidated, increasingly consolidated with depth; common laminations of silt and clay; occasional laminations with abundant carbonaceous material; grades to siltstone in part; increase ash and clay content with depth; porosity predominantly infilled with matrix; estimated very poor to occasional poor intergranular porosity, no oil show no cut. 4190' .4230' Coal = black to dark brownish black; predominantly very hard; commonly brittle; irregular, splintery and conchoidal fracture; predominantly tabular cuttings; vitreous to resinous luster; common very thin laminations of clay/ash; occasional grades to carbonaceous shale; occasional visible gas bleeds. 4230' .4275' Sand = light gray to brownish gray overall; very fine to medium with rare coarse grains; subangular to subround; moderately sorting; low to moderately sphericity; 60% quartz, 40% lithics; 50% unconsolidated, 50% weakly consolidated with ash clay matrix; non calcareous; porosity predominantly infilled with matrix; common iron stain and carbonaceous material; estimated very poor with occasional fair intergranular porosity, no fluorescence or cut. 4275' -4315' Clay = light gray to grayish brown; cohesive and adhesive; hydrofissile; mushy to clumpy consistency; malleable to crumbly; massive well rounded cuttings; earthy dull luster; smooth to gritty texture; occasional visible gradational contact with siltstone; common carbonaceous material; common ash. ,~ 4315' - 4355' Coal = black to dark brownish black; predominantly very hard; commonly brittle; irregular, splintery and conchoidal fracture; predominantly tabular cuttings; vitreous to resinous luster; common very thin laminations of clay/ash; occasional grades to carbonaceous shale; occasional visible gas bleeds. 4355' . 4405' Sand = light gray to greenish gray to whitish gray; very fine to medium with rare coarse grains; moderately to occasional well sorted; predominantly subangular; moderately to low sphericity; 60%-70% quartz 30%-40% lithics; 40% unconsolidated, 60% weakly consolidated with matrix and rare well consolidated with siliceous cement; abundant ash clay matrix infilling porosity; abundant laminations of clay/ash; grades to and interbedded with siltstone; estimated very poor intergranular porosity with no fluorescence or cut. 4405' - 4445' Siltstone = light gray to whitish gray; soft to firm; occurs as well rounded cuttings; no visible fracture; earthy with common sparkly luster; gritty to abrasive texture; occasional visible gradation from clay to silt to very fine sand; predominantly quartzose; abundant ashy laminations. 4445' . 4485' Coal = black to dark brownish black; predominantly to brittle; irregular. splintery, and conchoidal fracture; predominantly massive to tabular cuttings; vitreous to resinous luster; common very thin laminations of clay/ ash; common grades to carbonaceous shale; no visible gas bleeds. 4485' - 4520' Sand = medium light gray to light olive gray; fine to medium grains; moderately to well sorted; subround to subangular; moderately sphericity; consists of 60%-70% quartz 30%-40% lithics; 40% unconsolidated 60% weakly consolidated with clay and tuffaceous matrix; estimated very poor intergranular porosity. , ' U EPOCH 12 ~ ~ UNOCALe PEARL #1 ---~ 4520' - 4565' Claystone = light gray to very light gray; slightly adhesive; amorphous mushy to moderately lumpy consistency; pulverulent occasional malleable tenacity; no visible fracture or cuttings habit; dull earthy luster; smooth, clayey texture; massive structure; sand and silt size particles suspended within clay matrix. 4565' - 4600' Siltstone = medium light gray to medium gray; sectile tenacity; no visible fracture; massive to platy cuttings habit; greasy luster; silty, gritty grading to clayey and granular texture; massive to slightly laminated structure. 4600' - 4635' Coal = black to dark brownish black; predominantly to brittle; irregular, splintery, and conchoidal fracture; predominantly massive to tabular cuttings habit; greasy luster; common grades to carbonaceous shale; no visible gas bleeds. 4635' - 4670' Claystone = light gray to very light gray; cohesive and adhesive; hydrofissile; mushy; malleable to sectile; occurs as amorphous clumps; dull to occasional sparkly luster; smooth to gritty texture; contains abundant carbonaceous material; common grades to siltstone. 4670' - 4705' Siltstone = medium light gray to medium gray; sectile tenacity; no visible fracture; massive to platy cuttings habit; greasy luster; silty, gritty grading to clayey and granular texture; massive to slightly laminated structure. 4705' - 4740' Claystone = light gray to very light gray; cohesive and adhesive; hydrofissile; mushy; malleable to sectile; occurs as amorphous clumps; dull to occasional sparkly luster; smooth to gritty texture; contains abundant carbonaceous material; common grades to siltstone, 4740' - 4775' Sand = medium light gray to light gray; fine to medium grains; moderately to well sorted; subround to subangular; moderately sphericity; consists of 60%-70% quartz 30%-40% lithics; 60% unconsolidated 40% weakly consolidated with clay and tuffaceous matrix; estimated poor intergranular porosity. 4775' - 4810' Claystone = light gray to very light gray; cohesive and adhesive; hydrofissile; mushy; malleable to sectile; occurs as amorphous clumps; dull to occasional sparkly luster; smooth to gritty texture; contains abundant carbonaceous material; common grades to siltstone. 4810' -4840' Coal = black to brownish black; crunchy tenacity; planar to blocky occasional splintery fracture; flaky cuttings habit; greasy to resinous luster; smooth to matte texture; laminated; common grade to carbonaceous shale. 4840' - 4880' Siltstone = light gray to brownish gray; sectile tenacity; no visible fracture or cuttings habit; dull to greasy occasional sparkling luster; silty, gritty grading to granular, abrasive texture; laminated grading to fissile structure; abundant carbonaceous and ash laminations. 4880' - 4915' Claystone = light gray to very light gray; cohesive and adhesive; mushy to lumpy; malleable to sectile; occurs as amorphous clumps; dull to occasional sparkly luster; smooth to gritty texture; contains abundant carbonaceous material; common grades to siltstone. ,.---, IJ EPOCH 13 ,,-.... ~ UNOCAL8 PEARL #1 --, 4915' - 4960' Coal = black to brownish black; crunchy tenacity; planar to blocky occasional splintery fracture; flaky cuttings habit; greasy to resinous luster; smooth to matte texture; laminated; common grade to carbonaceous shale. 4960' - 4995' Carbonaceous Shale = brownish black to grayish brown occasional very dusky red; brittle to crunchy grading to malleable; splintery to earthy fracture; no visible cuttings habit; greasy to dull; smooth to gritty texture; fissile; very silty. 4995' - 5040' Sand/Sandstone = medium light gray to medium gray; fine to medium grains; moderately to well sorted; subround to subangular; moderately sphericity; 70% quartz, 30% lithics; 40% unconsolidated, 30% weakly consolidated within clay matrix; 30% consolidated in lithified friable sandstone grading to siltstone; estimated poor to fair intergranular porosity; no fluorescence. 5040' - 5075' Sand = medium light gray to light gray; fine to coarse grains; moderately to well sorted; subround to subangular; moderately sphericity; consists of 60%-70% quartz 30%-40% lithics; 70% unconsolidated 30% weakly consolidated with clay and tuffaceous matrix; estimated poor intergranular porosity. Note: switch to oil based mud at 5071' overall sample quality dramatically improved. 5095' - 5145' Siltstone = brownish gray to medium gray; sectile to mod hard tenacity; slightly planar to irregular fracture; occasional scaly to massive cuttings habit; greasy luster, sparkling on fresh surfaces; silty, gritty grading to granular, sucrosic texture; laminated to thinly bedded with carbonaceous material; grading to sandstone and clay; slightly siliceous. /~. 5145' - 5185' Sandstone = medium gray to medium light gray; quartzose framework; fine to very fine; well to very well sorted; rounded; high sphericity; soft to friable occasional mod hard; clay matrix supported; thinly bedded to lam with abundant carbonaceous material, ash and silt; poor to very poor estimated intergranular porosity. 5185' - 5215' Coal = black to brownish black; crunchy tenacity; block to splint occasional conchoidal fracture; flaky cuttings habit; greasy to resinous luster; smooth to matte texture; laminated; common grade to carbonaceous shale. 5215' - 5260' Claystone = medium gray to medium light gray; strongly cohesive; stiff consistency; sectile to stiff; írregular to slightly planar fracture; slightly curved cuttings habit; greasy to dull occasional sparkling luster; clayey grading to silty texture; very finely laminations to massive; grading to siltstone and carbonaceous shale. 5260' - 5305' Siltstone = brownish gray to medium gray; seetHe to mod hard tenacity; slightly planar to irregular fracture; curved to massive cuttings habit; greasy luster, sparkling on fresh surfaces; silty, gritty grading to granular, sucrosic texture; laminated to thinly bedded with stringers of carbonaceous material and clay. ~ (J EPOCH 14 ,'-""" .--.. UNOCAL8 PEARL #1 ,...---. 5305' - 5365' Claystone = medium gray to medium light gray; strongly cohesive; stiff consistency; sectile to stiff; irregular to slightly planar fracture; slightly curved cuttings habit; greasy to dull occasional sparkling luster; clayey grading to silty texture; very finely laminations to massive; grading to siltstone and carbonaceous shale. 5365' - 5405' Sandstone = medium gray to medium light gray; quartzose framework; fine to medium grained; well sorted; rounded; high sphericity; soft to friable occasional mod hard; clay matrix supported; thinly bedded to lam with abundant carbonaceous material, ash and silt; poor to very poor estimated intergranular porosity; no oil indicators. 5405' - 5435' Coal = black to brownish black; crunchy tenacity; block to splint occasional conchoidal fracture; flaky cuttings habit; greasy to resinous luster; smooth to matte texture; laminated; common grade to carbonaceous shale. 5435' - 5480' Siltstone = pale yellowish brown to medium light gray, occasional medium gray; sectile to mod hard tenacity; irregular fracture; massive cuttings habit; greasy luster; gritty grading to granular, sucrosic texture; laminated to thinly bedded with stringers of carbonaceous material and clay; no reaction to HCr. 5480' - 5535' Sand/Sandstone = light gray to very light gray occasional pale yellowish brown; quartz framework; fine to medium grained with occasional coarse grains; fair to well sorted; subround to subangular; high to mod sphericity; bit impacted; 80% quartz, 20% mixed igneous and metamorphic lithics; 80% consolidated, 20% unconsolidated; matrix supported; abundant ash and carbonaceous material; poor estimated intergranular porosity; thinly bedded to laminated; no oil indicators. ,'----" 5535' - 5570' Coal = black to grayish black; crunchy tenacity; irregular to splintery fracture; massive to flaky cuttings habit; greasy to resinous luster; smooth occasional gritty texture; massive structure; grading to carbonaceous shale; no gas bleeds. 5570' - 5625' Sand/Sandstone = light gray to very light gray occasional pale yellowish brown; quartz framework; fine to medium grained with occasional coarse grains; fair to well sorted; subround to subangular; high to mod sphericity; bit impacted; 80% quartz, 20% mixed igneous and metamorphic lithics; 80% consolidated, 20% unconsolidated; matrix supported; abundant ash and carbonaceous material; poor estimated intergranular porosity; thinly bedded to laminated; no oil indicators. 5625' - 5675' Claystone = medium gray to medium light gray; very cohesive; stiff consist; stiff to sectile tenacity; irregular, earthy to occasional planar fracture; massive to curved PDC grooved cuttings habit; greasy to dull luster; clayey grading to silty, gritty texture; laminated to thinly bedded with abundant carbonaceous material and ash; common grading to siltstone. 5675' - 5705' Siltstone = medium greenish gray; firm to rare hard; irregular fracture; elongate PDC bit deformed cuttings; dull earthy luster; gritty to abrasive texture; commonly interbedded with clay; very ashy; predominantly quartzose. /'-', ~ EPOCH 15 ~ ~ UNOCAL8 PEARL #1 "--. 5705' - 5745' Sandstone/Sand = whitish gray to light gray; very fine to medium with occasional to common coarse and bit fracture very coarse to pebble size; subangular to subround; poor to mod sorting; low to mod sphericity; 70% quartz, 30% lithics; 60% consolidated; ash matrix infilling porosity; grain supported grading to matrix support in part; estimated very poor intergranular porosity; no shows. 5745' - 5780' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to gritty texture; occasional visible banding; very thin laminations of ash; rare grading to siltstone. 5780' - 5820' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale. 5820' - 5855' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to gritty texture; occasional visible banding; very thin laminations of ash; rare grading to siltstone. ~- 5855' - 5885' Siltstone = medium greenish gray; firm to rare hard; irregular fracture; elongate PDC bit deformed cuttings; dull earthy luster; gritty to abrasive texture; commonly interbedded with clay; very ashy; predominantly quartzose. 5885' - 5925' Sandstone = light whitish gray overall; fine to medium with occasional coarse grains; predominantly subround; mod to well sorted; mod sphericity; 70%-80% quartz, 20%-30% lithics; 70%-80% consolidated with matrix; consolidated chips show complete infilling with ash; abundant ash laminations; rare cy laminations; predominantly grain supported with common matrix supported; estimated very poor intergranular porosity. 5925' - 5965' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; occasional visible gas bleeds. 5965' - 6005' Carbonaceous Shale = dark brown to blackish brown; cohesive; crumbly to rare brittle; irregular to sub planar fracture; flaky to massive cuttings; waxy to sub resinous luster; common thin banding; common ashy laminations; common very carbonaceous rich laminations; rare visible gas bleeds. 6005' - 6040' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to gritty texture; occasional visible banding; very thin laminations of ash; common grading to siltstone. 6040' - 6080' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to gritty texture; occasional visible banding; very thin laminations of ash; common grading to siltstone; common laminations of carbonaceous material; common coal cavings. ~. (J EPOCH 16 r'" ~ UNOCAL8 PEARL #1 ,~- 6080' - 6120' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; occasional visible gas bleeds. 6120' - 6150' Clay = light gray to medium greenish gray; firm; crumbly; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth texture; occasional very thin laminations of ash; occasional grading to siltstone. 6150' - 6190' Coal = black to grayish black with occasional brownish black; crunchy to occasional brittle; irregular, splintery fracture; massive to flaky cuttings habit; greasy to waxy occasional dull luster; smooth texture; slickensidal impact marks on cuttings surfaces; no visible gas bleeding. 6190' - 6225' Claystone = medium dark gray to brownish gray; very cohesive; stiff consistency; stiff to sectile tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; greasy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. 6225' - 6285' Siltstone = medium gray to dusky brown; tough to sectile tenacity; irregular fracture; curved PDC cuttings habit; waxy to dull luster; silty, gritty grading to granular texture; thinly bedded to laminated with abundant carbonaceous material and sand; gradational to sandstone; very slightly siliceous; no reaction to HCI. ,~- 6285' - 6335' Sand/Sandstone = medium light gray to light gray overall; quartz framework; fine to very fine with rare individual medium grains; well sorted; round to subround; high sphericity; 70% quartz, 30% igneous and metalithics; grain supported cemented in clay/ash matrix; laminae with carbonaceous material stringers; grading to siltstone; poor estimated intergranular porosity; no oil indicators. 6335' - 6370' Coal = black to grayish black with occasional brownish black; crunchy to occasional brittle; irregular, splintery fracture; massive to flaky cuttings habit; greasy to waxy occasional dull luster; smooth texture; thinly bedded structure; no gas bleeds. 6370' - 6430' Sand/Sandstone = very light gray to pale yellowish brown in overall color; quartz framework; fine to medium grained; fair sorting; subround to subangular; mod sphericity; 60% consolidated, 40% unconsolidated; sandstone firm friable to mod hard; predominantly grain with occasional matrix supported; carbonaceous material and ash stringers common in laminated matrix supported specimens; massive structure in grain supported specimens; poor estimated intergranular porosity; no hydrocarbon indicators. 6430' - 6465' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to gritty texture; occasional visible banding; very thin laminations of ash; common grading to siltstone; common laminations of carbonaceous material. 6465' - 6505' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy Juster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; occasional visible gas bleeds. ~- U EPOCH 17 ~ ,..-.., UNOCALe PEARL #1 /-, 6505' - 6540' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to occasional gritty texture; occasional banding visible; rar~ very thin laminations of ash; occasional grading to siltstone; rare laminations of carbonaceous material. 6540' - 6575' Clay = light gray to medium greenish gray; firm; crumbly to pulverulent; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to occasional gritty texture; occasional banding visible; rare very thin laminations of ash; occasional grading to siltstone; rare laminations of carbonaceous material. 6575' - 6615' Sandstone = light gray to whitish gray overall; fine to medium with rare to occasional coarse; angular to subround; mod to well sorted; mod sphericity; 60%-70% quartz and 30%-40% lithics; approx 90% consolidated; predominantly matrix supported; porosity predominantly infilled with ash matrix; common laminations of ash; occasional laminations of clay; estimated very poor intergranular porosity; no shows. 6615' - 6655' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; occasional visible gas bleeds. ~ 6655' - 6705' Sand/Sandstone = very light gray to whitish gray; very fine to medium with rare very coarse and bit fracture pebble; angular to subangular; moderately to poor sorting; low sphericity; 70% quartz, 30% lithics; 50% consolidated; abundant clay/ash matrix in consolidated chips; occasional laminations of carbonaceous material; commonly grades to siltstone; matrix has slight HCI reaction in part; porosity predominantly infilled; estimated very poor intergranular porosity; no fluorescence; no show. 6705' - 6740' Claystone = medium dark gray to brownish gray; very cohesive; stiff consistency; stiff to sectile tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; greasy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. 6740' - 6780' Sand = dark gray to grayish black in overall color with individual grains black, translucent, and gray; quartz framework; fine to very fine with rare medium grains; well sorted; subround; moderately to high sphericity; unconsolidated; 60% igneous and metamorphic lithics. 40% quartz, with abundant carbonaceous flakes; good estimated intergranular porosity. 6780' - 6830' Sand/Sandstone = medium light gray to light gray overall; quartz framework; fine to very fine with rare individual medium grains; well sorted; round to subround; high sphericity; 70% quartz, 30% igneous and metalithics; grain supported; cemented in clay/ash matrix; laminae with abundant ash; porosity predominantly infilling with clay/ash; estimated very poor grading to poor intergranular porosity; no visible fluorescence; no cut. 6830' - 6865' Coal = black to grayish black with occasional brownish black; crunchy to occasional brittle; irregular, splintery fracture; massive to flaky cuttings habit; greasy to waxy occasional dull luster; smooth texture; thinly bedded structure; no gas bleeds. ~- fJ EPOCH 18 ~ .~ UNOCAL8 PEARL #1 /""~ 6865' - 6915' Sand/Sandstone = medium light gray to pale yellowish brown; quartz framework; very fine to fine; well sorted; subround to occasional round; high sphericity; friable to firm friable; 60% consolidated, 40% unconsolidated; 60% grain 40% matrix supported; matrix clay/ash; sandstone laminated with common carbonaceous stringers; estimated poor to very poor intergranular porosity; no fluorescence. 6915' - 6975' Siltstone = medium gray to dusky brown; tough to sectile tenacity; irregular fracture; curved PDC cuttings habit; waxy to dull luster; silty, gritty grading to granular texture; thinly bedded to laminated with abundant carbonaceous material and sand; gradational to sandstone; no reaction to HC!. 6975' - 7025' Sand/Sandstone = medium gray to pale yellowish brown; quartz framework; very fine to fine; well sorted; subround to occasional round; high sphericity; friable to firm friable; 60% consolidated, 40% unconsolidated; 60% grain 40% matrix supported; matrix clay/ash; sandstone laminated with common carbonaceous stringers; estimated poor to very poor intergranular porosity. 7025' - 7060' Claystone = medium dark gray to dusky brown; very cohesive; stiff consistency; stiff to sectile tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; greasy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. 7060' - 7090' Sandstone = light gray to whitish gray overall; predominantly fine to medium with rare coarse grains; angular to occasional subround; moderately to poor sorting; moderately sphericity; 70% quartz; 30% lithics; abundant clay/ash matrix infilling porosity; estimated very poor intergranular porosity; no shows ~ 7090' - 7135' Sandstone = very light gray to whitish gray; fine to medium with occasional very fine and rare coarse; angular to occasional subround; poor to moderately sorting; low to moderately sphericity; 70%80% quartz, 20%-30% lithics; 60%-80% consolidated; abundant decreasing to common clay ash matrix; grain supported with rare matrix support; common laminations of ash; rare carbonaceous streaks; estimated predominantly poor intergranular porosity; no oil indicators. 7135' - 7180' Sandstone = light gray to whitish gray overall; very fine to medium with rare coarse grains; moderately sorting with occasional well sorted fine and very fine laminations; subangular to subround; moderately sphericity; 70% quartz, 30% lithic; common clay/ash matrix grading to occasional in part; abundant laminations of ash in lower section; porosity predominantly infilling with matrix with occasional open porosity; grades to siltstone in part; estimated very poor with occasional fair intergranular porosity; no oil shows. 7180' - 7220' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; trace visible gas bleeds. 7220' - 7257' Claystone = medium dark gray to dusky brown; very cohesive; stiff consistency; stiff to crumbly tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; earthy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. .~ U EPOCH 19 ~ ~ UNOCALe PEARL #1 ~, Note: core #17257'-7341' 7265' - 7295' Claystone = brownish gray to dusky brown; very cohesive; stiff consistency; stiff to section tenacity; irregular fracture; curved cuttings habit; waxy to dull luster; clayey to silty texture; lam to very thinly bedded structure. 7295' - 7340' Sandstone = medium light gray to very light gray; very fine to fine grain with occasional medium and coarse; subangular to subround; poor to moderately sorting; low to moderately sphericity; 80% quartz, 20% lithics; 80% consolidated; abundant clay/ash matrix; predominantly grain with occasional matrix support; common laminations ash and carbonaceous material; estimated poor with occasional fair intergranular porosity; friable to firm friable; no oil indicators. 7340' - 7385' Siltstone = medium gray to dusky brown; tough to sectile tenacity; irregular fracture; curved PDC cuttings habit; waxy to dull luster; silty, gritty grading to granular texture; thinly bedded to laminated with abundant carbonaceous material and sand; gradational to fine sandstone and gritty claystone; no reaction to HCI. 7385' - 7420' Claystone = medium dark gray to dusky brown; very cohesive; stiff consistency; stiff to crumbly tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; earthy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. ~ 7420' - 7480' Sandstone = medium light gray to very light gray; very fine to fine grain with occasional medium and coarse; subangular to subround; poor to moderately sorting; low to moderately sphericity; 80% quartz, 20% lithics; 80% consolidated; abundant clay/ash matrix; predominantly grain with occasional matrix support; common laminations ash and carbonaceous material; estimated poor with occasional fair intergranular porosity; no oil indicators. 7480' - 7515' Clay = light gray to medium greenish gray; firm; crumbly to brittle; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to occasional gritty texture; occasional banding visible; rare very thin laminations of ash; occasional grading to siltstone; rare laminations of carbonaceous material. 7515' - 7550' Siltstone = light gray to greenish gray; firm to crumbly; irregular PDC bit deformed cuttings; dull earthy luster; gritty texture; occasional visible laminations; predominantly quartzose; grades to very fine sandstone; very argillaceous, 7550' - 7590' Coal = black to brownish black; hard to firm; irregular to sub blocky fracture; wedge-like to elongate to subtabular cuttings; vitreous to resinous to greasy luster; smooth to matte texture; abundant clayey laminations; commonly grades to carbonaceous clay/shale; trace visible gas bleeds. 7590' - 7645' Sandstone/Conglomerate = light gray overall; fine to coarse with abundant bit broken very coarse and pebble grains; predominantly very poor sorted; angular to occasional subround; low to moderately sphericity; 70% quartz, 30% lithic; 95% consolidated; trace calcareous in part; abundant clay/ash matrix; predominantly easily friable with occasional well siliceous cemented chips; porosity predominantly ¡nfilled with clay/ash; sand at approximately 7577' shows open porosity; estimated very poor with rare fair intergranular porosity; oil indicators masked by oil based mud. ~ ~ EPOCH 20 r.. .",""", UNOCAL8 PEARL #1 .~ 7645' - 7680' Clay = light gray to medium greenish gray; firm; crumbly to brittle; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to occasional gritty texture; occasional banding visible; rare very thin laminations of ash; occasional grading to siltstone; rare laminations of carbonaceous material. 7680' - 7745' Sandstone/Conglomeratic Sand = medium light gray to light gray in overall color with individual grains translucent, milky white and gray; quartz framework; fine to medium grained with common bit impacted coarse to pebble sized grains; poor to predominantly very poor sorting; angular to subround; low to very low sphericity; 50% consolidated in friable infilled clay/ash matrix; 50% unconsolidated with occasional open porosity; 70% quartz, 30% mixed lithic; poor to fair estimated intergranular porosity; no visible oil indicators. 7745' - 7790' Coal = black to brownish black, dusky brown when grading to carbonaceous shale; brittle to crunchy tenacity; irregular, splintery fracture; flaky to massive cuttings habit; greasy, resinous luster; smooth to matte texture; massive to thinly bedded; gradational with carbonaceous shale; no visible gas bleeds. 7790' - 7825' Clay = light gray to medium greenish gray; firm; crumbly to brittle; platy PDC bit deformed cuttings; dull earthy to waxy luster; smooth to occasional gritty texture; occasional banding visible; rare very thin laminations of ash; occasional grading to siltstone; rare laminations of carbonaceous material. ~ 7825' - 7865' Sandstone = light gray overall; fine to coarse with occasional bit broken very coarse and pebble; predominantly subangular; predominantly poor sorting; moderately sphericity; 70% quartz, 30% lithics; consolidated with occasional loose coarser grains; abundant clay/ash matrix; porosity predominantly infilling; rare cuttings showing open porosity; trace calcareous; estimated very poor intergranular porosity; no shows. 7865' - 7910' Siltstone = medium gray to dusky brown; tough to sectHe tenacity; irregular fracture; curved PDC cuttings habit; waxy to dull luster; silty, gritty grading to granular texture; thinly bedded to laminated with abundant carbonaceous material and sand; gradational to fine sandstone and gritty claystone; no reaction to HCI. 7910' - 7945' Claystone = medium dark gray to dusky brown; very cohesive; stiff consistency; stiff to crumbly tenacity; irregular to no visible fracture; massive to curved PDC cuttings habit; earthy to dull; clayey grading to silty texture; laminated with abundant carbonaceous material and silt. 7945' - 8000' Sandstone/Conglomeratic Sand = medium gray to very light gray with occasional grayish orange and moderately yellowish green; quartz framework; fine to medium grained with occasional very coarse to pebble sized grains; fair to poor sorting; subround to subangular; moderately to low sphericity; common bit impacted mechanical abrasion; 80% quartz, 20% lithics; 60% consolidated within clay/ash matrix, 40% unconsolidated; fair to poor estimated intergranular porosity; no oil indicators. Total Depth 8000' md 03/05/2002 0030hrs /---' (:I EPOCH 21 o"""'~~~~~ ~.. ." ;~. /"'. ". ;~~ - ~.~P..f -- r"')! """<:6.ox "~,' C..3151 to C-311¡5 . .~~~,. . . .'~~"" , Please use boxes and tags' ¡'n o~der S fCOl1)pan;/RI9: UAlOolhASI<~ / /..f<,¡! ~ .s::. 0 ~ ~ Well: PtllR.L1f J. <to- :=) 0 Sampling Manifold # ~ Company/Rig: ilAAX..AI. filAs~ A jI-l1l/J.'" c¡ z >< . --- . - 0 ~ ~ Well:. ¡/éJJI<¿ 11 1. u ~ Sampling Manifold # ~ Depth 1.-1 0" G. U. /.J 1 (j U') ~ t? Date: Þtb ~ "'¡loC1.Time: r; I S (.) Sampled by: A"j '" ~ w ('J~{.. k" f'\& J..., ("II Depth '" I 56 It) ~ Da~~: °Ý"-~ Time: ¡!:Joe (,) Sampled by: J1..,J,.~v-' f3LCtw ß1 r'\ .G.U... ~l~. ; , . ~ Depth "-I ~ 0 I G. U. 9~ ~ "it ' ~ Date: C, 7/ 'Z 4..j Time: f ~ "10 (,) ,Sampled by: f) 1),,(/ Á c; ,,~^ ~ Depth 4-' 3l .G.u." 6"0 It) ~ Date: 01/1.. Lot Time:. "'1;2..0 (,)..sampied by: A. OUt U~N.~~ ~ ')~1? . '. ."",".0 ""'~Jr II) 0:; 4~1~.~ G,U. ',{, tJty}" ~ ~'. . ~ Date::.'-:.. J - ,d '"{ - C;..~ Time: .~ (j:O\J~ , "'- ..- 0 \\ {' . \ ',\¡ Sampled by:. L \J-\'~' \¡-(~ \t ':'~~~~J!:. Y Ll J.' 7 ., ~ ~~pth. U ,'" ~ t? Date: J. ~ ;~ Y - 01. . Time: Jú :(),O . , (.) 'Sampled by: 1)., û,*ke t- Depth 'i1Ÿ <0 '" G,U, " 1v It) ~ t? Date: ;J. J5 - D'~ Time: -:73 ~ .~t) (.) Sampled by: 'D. \)~ , ~ Depth.- ~ 3 \; 7. G. u. '1 t! 7.. ) ~ \ .- ,j t? Date: ¡..:~ \.0 ", OJ. Tima: 0". 4" (J Samplød by: b,. O+rke., . .' ~, G.U. f; ( G.U. t.o Î 5'", .' '.' ;" en Depth ... S'\CO It) .." ' .' '. ~ . Date: o~/~'6 Time:' '.00 ., (J Sampled by: A. ß"".~c. ytU\ '-.. . g Depth 5"1. YO G.U, . .40 ~ t? Date: 0 'l./1A £ Time: II ~ 5 (.) Sa~pled by:. A. r}1,.. t h~ "'c" '" .r I l l ; Depth -- 6 I ;).:3 ; Date: al/;¡6 0 Sampled by: A. ß", kc. h~" ... G.U. /01 "'Time: " IS - I ~ C-3151 to C43175 C-3151 to C-3175 ¡"1)'~~ \ . " t:;,:;' ~~~::"\::~~""""."""';,"'::. " ,., .."" i C'I Depth' fn'f:ö'c>d. ~""~~ (Ø ~ Date: ,). - ':;7- O.~ Time: 1\ .,'~ '.0 ,,<.J Sampled þy: \.'). D~~$t.. ,~~., -, ,- , , c~ ~g9~l ,/ G.U, ~\ï~ ~ Depth -", , ~ Date: '1.. 1 B . (, J Time: (): 0 ~ 0 Sampled by: 'C~\ ~ Ìc.{.. I bGìD ~ G.U. \ bS \i , ~~ 'J<Ö . b}'Time: O~;l7 D\\\~ '~111~~~ ~, 'j"..., ~, , ",' : " '". ,:: ~...,. ,"'. G.U."" It, ßu, ~ Depth CO T- ~ Date: (.) ~"""'" -~ :i~""'" "'::- '~".'i , . ',.,.. ' ".¡.., ,--"" 'fI!!'k' en Depth ',/ q J (þ ~ Date: O'Lj"l ~ Time:' t' S S <.J Sampled by: t:J. () to. (, ke. Y\ ~ Î' , G.U. ~OO ~ ~ Depth T- t? Date: ~~:~ Jt~, -- 718c¿ ~ G.U:' , 'tBv ':~~i S - , -' $d Time: J. (): of1 (C) \ ~\;<e, En Sampled by: T- Depth ..... ' ~ t1 Date: (.) \,,:'~/ r'jc15 ~ G.U. L\,Q~:':",t 1 - ,- ()~, Time: "~ 0: d 6' ' , - ' Ù \, ~~, ~" Sampled by: ' "I Sampled by: ., " ,~ a, :A / .,'lffy ',;-r,-:',: lot) Depth 10\1.0 G.U. t~dv N Depth ,-'¿J.. "1' , ,G.U. ~2\J' ~ ..... ~ Date: d - ~ \~ . Ç) ~ Time: Ù'1', d ~ :; Date: -'-~ - \ . 0 l ,Time:, ;;.. J . ...¡ 1. 0 Sampled by: Ù \i'\\t. 0 Sampled by: [) ~ ~'\'(r¿, to Depth 7/01.., G.U. ~C1... M Depth ., j1 \0 " .S:U. ¡ '-1'5 v co ..... ~/' Date: O~/:1.. ~ Time: O«ilOC ~ Date: 's - /. O~ Time: J~: '-13 0 Sampled by: IJ I ß(¡C~ r'\c. f' (.) Sampled by: l> + t !<e \ IÞ Depth.. -'1'3 ) G.U. :¿ 1i.¡ ~ Dater () ¥2 ~ Time: Oq:2 ~ 0 Sampled by: A, 15 U Ile. r." " ~ Depth '7 I 5" S G. U. Z "5 '"Î C? Date: 0 2/7 f Time: /0;0 0 Sampled by: A, /f v' (' ¡;~ ; iGf r.... /~ ~ Depth 7~ 3D" G,U, H4 u ..... ~ D'~: },',:,..]. ()d Time: 0 ~ 5'S' 0 Sampled by: "Ù'++ I('t'., '<\~, '. in, Depth ì î 'a ~ ,I' to- ~ Date: ~ - ~ - 0 J.Time: 0 Sampled by;' 0 t t \r(~, 4, G,U, \Q \ v ."\ . "\<;1 U '1,-:/ 'f '. " \' ~ C.3151 to C.3175 . "".../:/, , . '~'""", ,..-C-315'1 to C-3175 "i¡" ~, , "iI.;~'1 " ' ' ", ~;"!'" r----. ,-....... UNOCAL8 PEARL #1 .r---. DAILY CHRONOLOGY 02/16/02 Epoch on location to rig up and await spud. 2/17/02 Spudded hole and drilled from 112' to 265'. Pulled out of the hole. Pulled up stabilizer and collars. Ran in the hole to 265' and drilled forward at 40 to 70 feet per hour to 555'. 2/18/02 Drilled from 555' to 1690'. Stalling out twice at 1534'. Drilled from 1690' to 1800'. Pumped high viscosity sweep. Pulled out of the hole, cleaned stabilizer, balled up and monitored well. Ran in the hole to 1800' reaming from 1714'. Pumped sweep and ran survey. 2/19/02 Ran downhole geophysical logs. Laid down bails and elevators. Pulled up new bails for casing, float shoe and float collar. Ran 9.625" casing landed at 1793'. Conductor settled 8.75". Used truck to pull casing back into place. Circulated and conditioned mud. Nippled down flow line and bell nipple. Tested lines to 3000 psi. Dropped bottom plug, and pumped cement. 2/20/02 Continued cement job. Washed up cement units. Blew down same. Vacuumed out cellar. Set base plates in cellar (had to trip edges with torch to fit). Cleaned pit #1. Hooked up gas buster to possum belly. Changed bails and elevators. Pulled up a stand of heavy weight drill pipe and set pack-off. Unhooked koomey lines from hydril and nippled down diverter system. Nippled up well head spools. Tested 9.625" casing pack off to 3000 psi for 15 minutes. Nippled up spacer spool and BOP's. /"-'- 2/21/02 Tested all BOP's, kill line valve choke line, HCR, choke manifold floor safety valve, kelly valve to 250/3000 psi. Performed koomey test. Pulled test plug and installed wear bushing. Nippled down bell nipple. Thawed ice out of flow at shakers and nippled up flow line and bell nipple. Hooked up turn buckles to stack and installed flow line sensor. Laid down 8" aHA. Rigged up mouse hole and changed elevators. Rigged up to pull up drill pipe. 2/22/02 Pulled up and made up 48 joints. Made up BHA, oriented motor to 78 degrees. Service rig, crown, draw works, and top drive. Tripped into the hole to 925'. Pumped up survey at 925'. Ran in the hole to 1480' and pumped up a survey. Pressured tested casing to 2500 psi for 15 minutes. Ran in the hole tagging cement at 1705'. Drilled out cement, shoe, and 20 feet offormation to 1820'. Circulated and conditioned mud. Performed formation integrity test. Drilled from 1820' to 2317'. 2/23/02 Drilled from 2317' to 2784'. Circulated and conditioned the mud. Pulled out of the hole from 2784' to 2555'. Back reamed to shoe. Serviced top drive. Tripped in the hole from 1780' to 2684'. Washed down to 2784'. Drilled and slid from 2784' to 3534'. 2/24/02 Drilled from 3540' to 3809'. Conditioned and circulated the mud. Took a survey. Pulled out of the hole from 3809' to 3610'. Back reamed from 3610' to 2135'. Tripped in the hole from 2135' to 3719'. Washed down to 3809'. Drilled ahead to present depth. .'---' ~ EPOCH 22 ,~ ~. UNOCAL8 PEARL #1 ~ 2/25/02 Drilled to 5068'. Circulated and conditioned the mud. Took a survey and pulled out of the hole to 3742'. Back reamed from 4850' to 3742'. Pumped out from 3742' to 1963'. Serviced crown and blocks. Added spacer spool to bell nipple. Pulled up 24 joints. Ran in the hole to 5068'. Circulated; changed over to oil based mud. Cleaned pits 1 and 3. Drilled from 5068' to present depth. 2/26/02 Drilled to 6137. Circulated bottoms up. Wiper tripped to 4744. Pulled up 42 joints of drill pipe, and ran them into the hole. Drilled to 6205. 2/27/02 Rotated and slid from 6204 to 6628. Pulled out of the hole to 6415 to change out accuator on top drive. Ran in the hole and continued drilling to 6912. 2/28/02 Drilled to 7225. Rig ran low of fuel, pulled off bottom to wait for fuel truck. Drilled to 7257. Circulated bottoms up. Pulled out of the hole. Stood back BHA. Pressured tested BOP's to 3000 psi. Performed koomey test. Serviced rig. 3/1/02 Pulled up core barrel assembly, BHA. HWDP. Tripped into the hole to the show. Cut and slipped drill line. Serviced top drive. Tripped in the hole to bottom. Circulated hole clean. Cored from 7257 to 7341. Circulated bottoms up ~. 3/2/02 Circulated bottoms up. monitored well. Pumped dry job. Pulled out of the hole slowly to prevent swabbing. Monitored well at shoe. Handled BHA. Laid down inner core and barrel. Laid down mud motor assembly. Pulled up rotating drilling assembly. Made up BHA. Ran in the hole to 3661. Filled drill pipe and broke circulation. Pulled up 30 joints of drill pipe. Ran in the hole. Reamed to 7341. Drilled to 7417. 313/02 Drilled from 7417' to 7761'. 3/4102 Drilled to 7808. Pumped dry job. Pulled out of the hole to 7110. Worked on top drive replacing the IBOP valve and accuator. Tripped into the hole and drilled to 7862. Worked on the top drive. Drilled to TD at 8000. .~. ~ EPOCH 23 ~ ~ UNOCAL8 PEARL #1 SHOW REPORTS r-" Show Report No. 1 Depth Interval: 4005 to 4045 MD Total Feet: 40 4005 to 4045 TVD Bit Information: Type: HTC DP0622 Hours: 27.4 Averages: Before DurinQ After ROP (ftlhr) 83.5 170.6 73.0 WOB (x1000Ibs) 18.4 15.2 15.3 RPM 140 140 140 Mud weight 9.4 9.4 9.4 Total Gas 48.3 197 46.9 C1 (ppm) 9028 34261 9830 C2 (ppm) 23 83 2 C3 (ppm) 3 9 0 C4 (ppm) 0 0 0 C5 (ppm) 0 0 0 ~, Cuttings Fluorescence: None Color: Intensity: Cut: Mud Fluorescence: None Formation Description: Maximum 218.6 17 140 9.4 470 87345 276 33 0 0 Sand/Sandstone = light gray to whitish gray overall; very fine to medium w occasional coarse grains; moderately sorting; subangular to subround; moderately to low sphericity; 80% quartz 20% lithics with common to abundant mica, trace glauconite; unconsolidated and consolidated; consolidated: 50% grain supported 50% matrix supported; common clay and ash infilling porosity; estimated predominantly very poor to poor with common fair to good intergranular porosity; no visible oil indicators. Gas Sample(s) C-3151 Depth: 4011 Units: Logging Geologist: Andrew Buchanan ,-----, [:I EPOCH 470 24 /"""., ~ UNOCAL8 PEARL #1 .--- Show RepOrt No. 2 Depth Interval: 4136 to 4180 MD Total Feet: 44 4136 to 4180 TVD Bit Information: Type: HTC DP0622 Hours: 29.1 AveraQes: Before DurinQ After Maximum ROP (fUhr) 99.8 166 118.8 242.5 WOB (x1000Ibs) 9.7 6.5 13.8 16 RPM 140 140 140 140 Mud weight 9.5 9.5 9.5 9.5 Total Gas 75 186.8 105 217 C1 (ppm) 14678 36817 21239 42750 C2 (ppm) 8 11 4 12 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: ~, Mud Fluorescence: None Formation Description: Sand = light gray overall; very fine to medium with rare coarse grains; moderately sorting; subangular to subround; moderately to low sphericity; 70% quartz, 30% lithics; predominantly unconsolidated, increasingly consolidated with depth; common laminations of silt and clay; occasional laminations with abundant carbonaceous material; grades to siltstone in part; increase ash and clay content with depth; porosity predominantly infilled with matrix; estimated very poor to occasional poor intergranular porosity, no oil show no cut. Gas Sample(s) C-3152 Depth: 4156 Units: 213 Logging Geologist: Andrew Buchanan .~, r;t EPOCH 25 ¡I'""', ~ UNOCAL8 PEARL #1 ----', Show Report No. 3 Depth Interval: 4484 to 4500 MD Total Feet: 16 4484 to 4500 TVD Bit Information: Type: HTC DP0622 Hours: 33.4 Averaoes: Before Durina After Maximum ROP (ftlhr) 91.4 184.2 125.9 217.3 WOB (x1000Ibs) 13.9 12.1 11.4 19.8 RPM 140 140 140 140 Mud weight 9.8 9.8 9.8 9.8 Total Gas 102.5 305 199 680 C1 (ppm) 31925 71397 39365 253101 C2 (ppm) 0 0 0 0 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: ~" Mud Fluorescence: None Formation Description: Sand/Sandstone = Medium light gray to light olive gray; fine to medium grained; moderate to well sorted; subrounded to subangular; moderate sphericity; consists of 60-70% quartz, 30-40% lithics; 60% unconsolidated, 40% weakly consolidated with clay and ash matrix; estimated poor intergranular porosity. Gas Sample(s) C-3155 C3156 Depth: 4485 4487 Units: 680 675 Logging Geologist: Doug Ottke /----, fI EPOCH 26 "".-..., ~ UNOCAL8 PEARL #1 ~ Show Report No. 4 Depth Interval: 4735 to 4765 MD Total Feet: 30 4735 to 4765 TVD Bit Information: Type: HTC DP0622 Hours: 35.4 AveraQes: Before DurinQ After Maximum ROP (ftlhr) 95.1 135.4 125.9 217.3 WOB (x1000Ibs) 13.9 12.1 11.4 19.8 RPM 140 140 140 140 Mud weight 9.8 9.8 9.8 9.8 Total Gas 154.9 278.2 177.8 753 C1 (ppm) 30682 55143 35233 1492175 C2 (ppm) 14 19 9.2 58 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: ~. Mud Fluorescence: None Formation Description: Sand/Sandstone = Medium light gray to light gray; fine to medium grained; moderate to well sorted; subrounded to subangular; moderate sphericity; consists of 60-70% quartz, 30-40% lithics; 60% unconsolidated, 40% weakly consolidated with clay and ash matrix; estimated poor intergranular porosity. Gas Sample(s): C-3157 Logging Geologist: Doug Ottke Depth: 4746 Units: 712 ~, U EPOCH 27 ~ /~ UNOCAL8 PEARL #1 ~- Show Report No. 5 Depth Interval: 5042 to 5070 MD Total Feet: 28 5042 to 5070 TVD Bit Information: Type: HTC DP0622 Hours: 39.8 Averaaes: Before During After Maximum ROP (ftlhr) 100.6 75.8 155.7 156.9 WeB (x1000Ibs) 7.2 7.1 7.7 12.5 RPM 140 140 140 140 Mud weight 9.8 9.8 9.8 9.8 Total Gas 144 443 107 1002 C1 (ppm) 31556 76822 20027 219676 C2 (ppm) 0 0 0 0 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: ~- Mud Fluorescence: None Formation Description: Sand = medium light gray to light gray; fine to coarse grains; moderately to well sorted; subround to subangular; moderately sphericity; consists of 60%- 70% quartz 30%-40% lithics; 70% unconsolidated 30% weakly consolidated with clay and tuffaceous matrix; estimated poor intergranular porosity. Gas Sample(s) Depth: Units: Logging Geologist: Doug Ottke -~- ~ EPOCH 28 ",-..." ~ UNOCAL8 PEARL #1 ~. Show Report No. 6 Depth Interval: 5375 to 5400 MD Total Feet: 25 5375 to 5400 TVD Bit Information: Type: HTC DP0622 Hours: 41.2 AveraQes: Before DurinQ After Maximum ROP (ftIhr) 218.3 165.3 116 270.5 WeB (x1000Ibs) 5.4 6 1.3 20.3 RPM 140 140 140 140 Mud weight 10.2 10.2 10.2 10.2 Total Gas 162 366 248 410 C1 (ppm) 23986 28045 25732 54269 C2 (ppm) 0 0 0 0 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: .r-' Mud Fluorescence: None Formation Description: Sandstone = medium gray to medium light gray; quartzose framework; fine to medium grained; well sorted; rounded; high sphericity; soft to friable, occasionally moderately hard; clay matrix supported; thinly bedded to laminated with abundant carbonaceous material, ash and silt; estimated poor to very poor intergranular porosity; no oil indicators. Gas Sample(s) C-3158 Depth: 5387 Units: 407 Logging Geologist: Doug Ottke /---- (;I EPOCH 29 ~. ~ UNOCAL8 PEARL #1 ~' Show Report No. 7 Depth Interval: 5876 to 5902 MD Total Feet: 26 to TVD Bit Information: Type: HTC DPO622 Hours: 51.1 Averaaes: Before DurinQ After Maximum ROP (fUhr) 69.6 151.4 78.8 222.8 WOB (x1000lbs) 4.3 6.1 5.2 12 RPM Mud weight 10.2 10.2 10.2 10.2 Total Gas 76.3 118 89.1 133 C1 (ppm) 13399 20704 15596 23378 C2 (ppm) 19 15 8.5 17 C3 (ppm) 0 0 0 C4 (ppm) 0 0 0 C5 (ppm) 0 0 0 Cuttings Fluorescence: None Color: Intensity: None Cut: ,,-, Mud Fluorescence: Milky pale brownish yellow Formation Description: Sandstone = light whitish gray overall; fine to medium with occasional coarse grains; predominantly subround; mod to well sorted; moderate sphericity; 70%- 80% quartz, 20%-30% lithics; 70%-80% consolidated with matrix; consolidated chips show complete infilling with ash; abundant ash laminations; rare clay laminations; predominantly grain supported with common matrix supported; estimated very poor intergranular porosity. Gas Sample(s) C-3159 Depth: 5900 Units: 137 Logging Geologist: Andrew Buchanan /-- () EPOCH 30 ~, ~ UNOCAL8 PEARL #1 ~ - Show ReDOrt No. 8 Depth Interval: 7073 to 7106 MD Total Feet: 33 7072 to 7105 TVD Bit IQformation: Type: HTC DP0622 Hours: 79.5 AveraQes: Before DurinQ After Maximum ROP (ftlhr) 32.3 42.4 24.0 108.9 WeB (x1000Ibs) 9.0 4.6 11.4 14 RPM . Mud weight 10.1 10.1 10.1 10.1 Total Gas 63.2 125.6 114 203 C1 (ppm) 11091 21896 20941 34761 C2 (ppm) 18 27 24 35 C3 (ppm) 0 3 1 10 C4 (ppm) 0 0 0 C5 (ppm) 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: ~- Mud Fluorescence: Milky pale brownish yellow Formation Description: Sandstone = very light gray to whitish gray; fine to medium with occasional very fine and rare coarse; angular to occasional subround; poor to moderate sorting; low to moderate sphericity; 70%80% quartz, 20%-30% lithics; 60%- 80% consolidated; abundant decreasing to common clay ash matrix; grain supported with rare matrix support; common laminations of ash; rare carbonaceous streaks; estimated predominantly very poor intergranular porosity increasing to poor at -7103'; no oil indicators. Gas Sample(s) C-3166 Depth: 7102 Units: 202 Logging Geologist: Andrew Buchanan r-'. [:I EPOCH 31 ~, ~ UNOCAL8 PEARL #1 -, Show Report No. 9 Depth Interval: 7125 to 7160 MD Total Feet: 35 to TVD Bit Information: Type: HTC DP0622 Hours: 82.0 AveraQes: Before Durinq After Maximum ROP (ftIhr) 23.2 54.9 58.7 120.5 WeB (x1000Ibs) 11.2 9.8 12.3 11.0 RPM Mud weight 10.1 10.1 10.1 10.1 Total Gas 113.4 191.2 160.5 275 C1 (ppm) 20607 35351 29419 50794 C2 (ppm) 24 24 19 40 C3 (ppm) 1 5 2 10 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Intensity: Mud Fluorescence: Milky pale brownish yellow Color: Cut: Formation Description: Sandstone = light gray to whitish gray overall; very fine to medium with rare coarse grains; moderate sorting with occasional well sorted fine and very fine laminations; subangular to subround; mod sphericity; 70% quartz, 30% lithic; common clay/ash matrix grading to occasional in part; abundant laminations of ash in lower section; porosity predominantly infilling with matrix with occasional open porosity; grades to siltstone in part; estimated very poor with occasional fair intergranular porosity; no oil shows. Gas Sample(s): C-3167 C-3168 Depth: 7133' 7155' Units: 274 234 Logging Geologist: Andrew Buchanan /- f) EPOCH 32 ,-.., .-..... UNOCAL8 PEARL #1 /~" Show Report No. 10 Depth Interval: 7285 to 7315 MD Total Feet: 30 to TVD Bit Information: Type: Core barrel Hours: 7.4 AverCig~s: Before Durina After Maximum ,_..."... .. ROP (ftlhr) 10.2 26.1 16.4 67.1 WeB (x1000Ibs) 16.9 16.9 17.5 18.2 RPM Mud weight 10.2 10.2 10.2 10.2 Total Gas 35.9 101 73.7 152 C1 (ppm) 6465 18242 13611 27070 C2 (ppm) 0 0 0 0 C3(ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 Cuttings Fluorescence: None Color: Intensity: Cut: .~ Mud Fluorescence: Milky pale brownish yellow Formation Description: Sandstone = Medium light gray to very light gray; very fine to fine grained with occasional medium and coarse grains; subangular to subrounded; poor to moderate sorting; low to moderate sphericity; 80% quartz, 20% mixed lithics; 80% consolidated; abundant clay/ash matrix; predominantly grain, occasionally matrix supported; common ash and carbonaceous material laminations; estimated poor with occasional fair intergranular porosity; friable to firmly friable; no oil indicators. Gas Sample(s): C~3170 Depth: 7288' Units: 118 C-3171 7295' 140 Logging Geologist: Doug Ottke /-, () EPOCH 33 ~ ~ ,'~" UNOCAL8 PEARL #1 MUD RECORD Date Depth MW VIS PV YP Gel FL Sol OIW Sand MBT pH Pm CI- Ca 02/17/02 435 8.9 50 17 16 7/16/25 18.8 3.5 0/96.5 0.25 18.0 9.5 0.2 400 120 02/18/02 1800 9.3 80 26 30 10/26/36 12.8 9.3 0/90.7 1.00 24.0 9.0 0.1 1500 40 02/19/02 1800 9.2 48 18 11 2/4/12 16.4 6.0 0/94.0 1.00 20.0 9.0 0.1 900 20 02/20/02 1800 9.2 15 12 19 3/10/12 9.0 7.0 0/93.0 TR 17.5 9.0 800 20 02/21/02 1800 9.2 40 10 14 3/9/11 11.2 7.0 0/93.0 TR 17.5 9.0 0.2 800 40 02/22/02 2400 9.1 44 9 10 3/9/10 7.3 6.0 0/94.0 TR 17.5 9.5 0.35 1100 40 02/23/02 3575 9.4 46 10 11 3/7/8 5.6 7.0 0/93.0 TR 17.5 9.5 0.45 1000 60 02/24/02 4900 9.8 46 13 10 317/8 6.0 9.0 0/91.0 TR 20.0 9.5 0.45 800 60 Change to Oil Based Mud at 5071' Depth MW VIS PV yp Gel FL Sol OIW Pom CI- Salt Lime E Stab 02/25/02 5400 10.2 85 31 21 23/27/29 5.0 8.2 85/15 0.5 24000 21.15 0.65 1450 02/26/02 6257 10.1 141 32 28 24/32/33 4.6 9.1 84/16 0,5 24000 21.15 0.65 1540 02/27/02 6910 10.1 126 31 19 21/29/31 5.0 9.1 84/16 0.5 27000 23.18 0.65 1585 02/28/02 7257 10.2 137 31 18 22/28/31 5.0 9.2 82/18 0.3 31000 23.27 0.39 1610 03/01/02 7341 10.3 183 32 22 22/27/32 5.0 11.0 82/18 0.3 31000 23.27 0.39 1600 03/02/02 7419 10.1 126 28 15 19/26/30 5.0 9.2 84/16 0.3 31000 25.07 0.39 1405 03/03/02 7700 10.1 106 24 15 11/19/28 5.0 9.2 84/16 1.4 29000 24.48 1.82 1628 03/05/02 7985 10.1 97 23 13 16/28/29 6.0 10.0 87/13 1.5 26000 25.32 1.95 1690 ~ ~'- ~ EPOCH 34 ,~ ~ UNOCAL8 PEARL #1 ,~ SURVEY RECORD MD Incl Azim TVD N (+)/ S(-) E(+) / W(-) Total dipl At Azim DLS (ft) n (O) (ft) (ft) (ft) (ft) n (0/100ft) 405.82 0.86 225.22 405.80 -2.15 -2.16 3.05 225.22 0.21 869.15 0.84 225.22 869.08 -6.99 -7.04 9.92 225.22 0.00 1428.61 0.48 225.22 1428.51 -11.46 -11.46 16.27 225.22 0.07 1892.48 0.85 225.22 1892.35 -15.19 -15.19 21.57 225.22 0.08 2079.13 0.83 220.20 2078.98 -17.20 -17.16 23.57 224.94 0.04 2355.62 0.92 226.41 2355.43 -20.26 -20,07 24.30 224.72 0.05 2729.41 1.25 224.28 2729.16 -25.25 -25.09 28.51 224.81 0.09 2824.05 1.35 218.90 2823.77 -26,86 -26.51 35.59 224.63 0.17 2917.20 0.87 219.11 2916.90 -28.26 -27.64 37.73 224.37 0.52 3009.41 0.78 220.14 3009.10 -29.28 -28.49 39.53 224.21 0.10 3103.01 0.87 218.44 3102.69 -30.32 -30.34 40.85 224.05 0.10 3195.91 0.34 250.25 3195.59 -30.97 -30.03 42.19 224.12 0.65 3288.26 0.33 328.65 3287.94 -30.84 -30.43 43.14 224.62 0.46 3379.12 0.31 342.96 3378.80 -30.38 -30.64 43.15 225.25 0.09 3474.33 0.27 333.97 3474.00 -29.23 -30.82 42.96 225.84 0.06 3566.48 0.31 353.16 3566.15 -29.49 -30.94 42.74 226.38 0.11 3658.41 0.49 333.40 3658.08 -28.89 -31.15 42.48 227.15 0.24 3755.44 0.15 331.40 3755.11 -28.26 -31.47 42.30 228.08 0.15 ~ 3845.79 0.33 316.84 3845.46 -27.82 -31.78 42.24 228.80 0.10 3940.62 0.45 357.52 3940.28 -27.25 -31.99 42.02 229.57 0.31 4030.83 0.52 4.24 4030.49 -26.49 -31.97 42.52 230.36 0.10 4124.71 0-37 22.60 4124.37 -25.79 -31.82 40.96 230.98 0.22 4219.14 0.55 27.69 4218.80 -25.10 -31.50 40.28 231.44 0.20 4312.26 0.40 24,99 4311.91 -24.41 -31.15 39.58 231.91 0.16 4498.75 0.24 274.64 4498.40 -23.79 -31.27 39.29 232.73 0.29 4685.98 0.33 300.54 4685.63 -23.49 -32.12 39.79 233.83 0.08 4778.75 0.24 317.03 4778.57 -23.21 -31.48 39,92 234.46 0.13 4964.02 0.62 7.61 4963.66 -21.93 -32.62 39.30 236.08 0.27 5013.43 0.63 359.52 5013.07 -21.39 -32.58 38.98 236.71 0.18 5152.78 0.73 345.27 5152.41 -19.77 -32.82 38.31 238.93 0.14 5245.18 0.80 338.18 5244.80 -19.60 -33.20 38.06 240.74 0.13 5431.00 0.94 337.22 5430.60 -15.99 -34.28 37.82 244.99 0.08 5524.22 0.95 342.50 5523.81 -14.55 -34.81 37.72 247.31 0.09 5617.46 1.04 341.81 5617.03 -13.01 -35.30 37.62 249.77 0.10 5709.93 1.07 342.98 5709.49 -11.39 -35.82 37.58 252.36 0.04 5803.62 1.18 339.96 5803.16 -9.64 -36.40 37.66 255.16 0.13 5896.43 1.26 325.39 5895.95 -7.91 -37.31 38.14 258.04 0.34 5990.45 1.30 324.74 5989.94 -6.18 -38.51 39.01 260.88 0.05 6085.73 1.39 326.23 6085.20 -4.40 -39.74 39.98 263.68 0.01 6177.34 1.40 327.65 6176.78 -2.47 -41.00 41.07 266.55 0.04 6269.36 1.05 328.88 6268.78 -0.80 -42.03 42.04 268.91 0.38 6361.76 1.04 324.39 6361.17 0.61 -42.96 42.96 270.81 0.09 ~ 6454.82 1.00 325.71 6454.21 1.97 -43.91 43.95 272.56 0.05 6548.15 1.05 323.69 6547.53 3.33 -44.87 45.00 274.24 0.07 [I EPOCH 35 ".-.... ~ UNOCAL8 PEARL #1 /"~ MD Incl Azim TVD N (+)1 S(-) E(+) 1 W(-) Total dipl At Azim DLS (ft) n (O) (ft) (ft) (ft) (ft) (O) (0/100ft) 6644.46 1.42 322.94 6643,81 4.99 -46.11 46.38 276,18 0,38 6736.96 1.39 320.46 6736.29 6.77 -47.52 48.00 278.11 0.07 6829.97 1.51 324.09 6829.27 8.63 -48.96 49.71 280.00 0.16 6921.71 1.47 327.87 6920.97 10.61 -50.29 51.40 281.91 0.12 7012.73 1.49 326.51 7011.96 12.59 -51.57 53.08 283.72 0.04 7107.75 1.60 329.82 7106.95 14.76 -52.91 54.96 285.59 0.15 7204.54 1.58 328.95 7203.70 17.07 -54.28 56.90 287.46 0.03 ~ .~. n EPOCH 36 UNOCAL8 PEARL #1 BIT RECORD Bit # Size Vendor Type Serial Jets In Out Feet Hrs..()n ROP GRADE I 0 D L B G 0 R N U U E A T E T L A G A L R U S I E 0 N N G ( 1 12,25 HTC MXC1 3X181X15 112 1800 1688 13.2 127.9 2 8,5 HTC DP0622 1905644 7X10 1800 7255 5455 86.0. 63.4 2RR 8.5 HTC DP0622 1905644 7X10 7342 8000 658 39.3 16.7 ( ( , U ~~'CH ( 37 Unocal Ninilchik -~ ~, ". DAILY WELLSITE REPORT Pearl #1 REPORT FOR Harold Fahrlender/Jim Benson DATE Feb 18, 2002 TIME 00:00:00 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE DRI\:.LING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL ~ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DEPTH 484 YESTERDAY 300 ~ [:I EPOCH PRESENT OPERATION= Drilling Ahead 24 Hour Footage 184 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH CONDITION T/B/C REASON PULLED SIN INTERVAL JETS IN OUT FOOTAGE HOURS 184 2.4 LOW AVERAGE 27.3 @ 392 149.9 0 @ 0 0 0 @ 410 8.1 0 @ 0 0 0 @ 0 0 DEPTH: YP FL OIL MBl CURRENT AVG 82.5 0 11.9 0 0 ftlhr amps KJbs RPM psi HIGH 542.6 @ 354 0 @ 0 19 @ 466 0 @ 0 0 @ 0 PV SD HIGH LOW 3 @ 478 0 @ 385 0 @ 0 0 @ 0 CHROMATOGRAPHY(ppm) 0 0 @ 0 0 0 0 @ 0 0 0 0 @ 0 0 0 0 @ 0 0 0 0 @ 0 0 AVERAGE 0.9 0 0 @ 0 @ 0 @ 0 @ 0 @ LITHOLOGY IREMARKS Gels CL- pH Ca+ CCI TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 3.2 CURRENT BACKGROUND/AVG 3/3 GAS DESCRIPTION LITHOLOGY Sand, Sandstone, Conglomeratic Sand, Tuffaceous Claystone, Tuffaceous Siltstone, Carbonaceous Material. PRESENT LITHOLOGY Tuffaceous Claystone 50%, Tuffaceous Siltstone 20%, Sand 20%, Sandstone 10% DAilY ACTIVITY Drilled from 112' to 265'. Pulled out of the hole to 80', Pulled up stabalizer and collars, Ran in the hole to 265' and drilled SUMMARY forward at 40 to 70 feet per hour to current depth, Epoch Personel On Board= 4 Daily Cost $1685 Report by: Doug Ottke ,,----, /"'-.., ~ Unocal Nllnllchik DAILY WELLSITE REPORT g EPOCH ------- Peart #1 REPORT FOR Jim Benson JATE 2/19/02 TIME 00:00:00 DEPTH 1600 YESTERDAY 484 24 Hour Footage 1316 PRESENT OPERATION= Surveying hole and rigging up to run surface casing. CASING INFORMATION BIT INFORMATION NO. SIZE 1 12.25 TYPE MXC-1 SIN DEPTH INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 150 1600 1650 Casing Point HIGH LOW AVERAGE CURRENT AVG 527.7 @ 495 7.0 @ 1343 149.5 92.1 ftIh r @ @ amps 38 @ 1413 0 @ 1214 12.7 9.7 Klbs @ @ RPM @ @ psi DEPTH: 435 PV 17 YP 16 FL 18,6 Gels 7/16/25 CL- 400 SD 1/4 OIL 0/96.5 MBL 18 pH 9.5 Ca+ 120 CCI SURVEY DATA DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.9 VIS FC SOL 50 3.5 MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) ~ITCH GAS JTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(c-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 27 @ 1493 0 @ 701 4.9 TRIP GAS= 3u @ @ WIPER GAS= 0 CHROMA TOGRAPHY(ppm) SURVEY= 0 4987 @ 1027 32 @ 1102 950.6 CONNECTION GAS HIGH= 2 0 @ 1800 0 @ 1800 0,0 AVG= 1 0 @ 1800 0 @ 1800 0.0 CURRENT 0 @ 1800 0 @ 1800 0.0 CURRENT BACKGROUND/AVG 0 @ 1800 0 @ 1800 0.0 LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand, sandstone, claystone, siltstone, coal. PRESENT LITHOLOGY 40% sand, 40% claystone, 20% siltstone. DAILY ACTIVITY Drilled from 555' to 1690'. Stalling out twice at 1534', Drilled from 1690' to 1600'. Pumped high viscosity sweep. Pulled out of the hole, cleaned stabalizer, SUMMARY balled up and monitored well. Ran in the hole to 1800' reaming from 1714'. Pumped sweep, a Epoch Personal On Board= nd dropped survey. Daily Cost 4 Report by: $2642.00 -------- ~ Unocal Nllnilchik DAILY WELLSITE REPORT /'"" Pearl #1 REPORT FOR Jim Benson DATE 2-20-02 TIME 00:00:00 .~ U EPOCH PRESENT OPERATION: Pumping cement for surface casing. DEPTH 1800 YESTERDAY 1800 24 Hour Footage 0 CASING INFORMATION 9.625"@793' SURVEY DATA DEPTH AZIMUTH INCLINATION BIT INFORMATION NO. SIZE 1 12.25 SIN INTERVAL JETS IN OUT FOOTAGE HOURS 1x153x18 150 1800 1650 13.2 HIGH LOW AVERAGe @ @ @ @ @ @ @ @ @ @ DEPTH: 1800' PV 26 YP 30 FL 12.8 Gels SD 1% OIL 0/90,7 MBL pH TYPE MXC-1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC SOL 80 9.3% MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(unlts) r-GITCH GAS JTTlNG GAS HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ LlTHOLOGY/REMARKS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL VERTICAL DEPTH CONDITION T/BIC REASON PULLED Casing Point CURRENT AVG 10126/36 9 ftIh r amps Klbs RPM psi CL- 1500 Ca+ 40 CCI TRIP GAS: WIPER GAS: SURVEY= CONNECTION GAS HIGH: AVG: CURRENT CURRENTBACKGROUN~AVG GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% Sand, 40% Claystone, 20% Siltstone DAILY ACTIVITY Ran down hole geophysical log. laid down bails and elevators. Pulled up new bails for casing, float shoe and float collar. Ran 9.625" casing landed at 1793'. SUMMARY Conducter seWed 8,75". Used truck to pull casing back into place. Circulated and conditioned mud. Nippled down flow line and bell nipple. Tested lines to 3000 psi. Dropped bottom plug, and pumped cement Epoch Personel On Board: 4 Daily Cost $2646.00 Report by: Doug Ottke ~ .~ ~, Unocal Nilnilchik DAILY WELLSITE REPORT ~ EPOCH Pearl #1 ~ REPORT FOR Jim Benson DATE 2/21102 TIME 00:00:00 DEPTH 1800 YESTERDAY 1800 PRESENT OPERATlON= Changing out BOP stack. 24 Hour Footage 0 CASING INFORMATION 9.625"@1793' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE 1 12.25 TYPE MXC-1 SIN JETS 1x153x18 INTERVAL IN OUT FOOTAGE HOURS 150 1800 1650 13.2 HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH: 1800' 12 YP 19 FL 9,8 Gels tr OIL 193 MBL 17.5 pH CONDITION TIBIC REASON PULLED Casing Point DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC 2/ SOL CURRENT AVG 50 7 PV SD 3110/12 9.0 nthr amps Klbs RPM psi CL- 800 Ca+ 20 CCI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) ~rrCH GAS JTTlNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3} BUTANE(C4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ LlTHOLOGY/REMARKS TRIP GAS= WIPER GAS= SURVEY", CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUNillAVG GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% Sand, 40% Claystone, 20% Siltstone. Continued cement job. Washed up cement units. Blew down same. Vacuumed out cellar. Set base plates in cellar (had to trip edges with torch to fit). Cleaned pit #1. Hooked up gas buster to possom belly. Changed bails and elevators. Pulled up a stand of heavy weight drill pipe and set pack-off. Unhooked koomey lines from hydril and nippled down diverter system. Nipple<! upwell head spools. Tested 9.625" casing pack off to 3000 psi for 15 minutes. Nippled up spacer spool ano BOP's. Epoch Personel On Board'" 4 Daily Cost $2721.00 Report by: Doug Ottke DAilY ACTIVITY SUMMARY ~ ,~ '---, Unocal Nllnilchik DAILY WELLSITE REPORT ~ EPOCH Peart #1 ~, REPORT FOR Jim Benson DATE 2-22-02 TlME 00:00:00 DEPTH 1800 YESTERDAY 1800 24 Hour Footage 0 PRESENT OPERATION= Pulling up pipe. CASING INFORMATION 9.625"@1793' SURVEY DATA DEPTH INCLINATlON AZIMUTH VERTICAL DEPTH BIT INFORMATlON NO, SIZE 1 12.25 lYPE MXC-1 SIN JETS 1x153x18 INTERVAL IN OUT FOOTAGE HOURS 150 1800 1650 13.2 HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH: 1800' 12 YP 19 Fl 9,6 Gels tr Oil 193 MBl 17.5 pH CONDITION T/BIC REASON PULLED Casing Point DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC 21 SOL CURRENT AVG 50 7 PV SD 3/10/12 9.0 ftlhr amps Ktbs RPM psi CL- 800 CaT 20 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(unlts) /""1TCH GAS rTTlNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ lITHOLOGY/REMARKS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND~VG GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% Sand, 40% Claystone, 20% Siltstone DAILY ACTIVllY Tested all BOP's, kill line valve choke line, HCR, choke manifold floor safety valve, kelly valve to 250/3000 psi. Performed koomey test. Pulled test plug and SUMMARY installed wear bushing. Nippled down bell nipple. Thawed ice out of flow at shakers and nipple<! up flow line and bell nipple. Hooked up tum buckles to stack and installed flow line sensor. Laid down 8" BHA. Rigged up mouse hole and changed elevators. Rigged up to pull up drill pipe. Epoch Personel On Board= 4 Daily Cost $2721.00 Report by: Doug Ottke ,---... Unocal Nilnilchik Pearl #1 /"'~ REPORT FOR Jim Benson DATE Feb 23,2002 TIME 00:00:00 CASING INFORMATION 9.625'@1793' SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5 lYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.1 VIS FC 21 SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) .~ITCH GAS JTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ~ .......... DAILY WELLSITE REPORT ~ EPOCH DEPTH 2317 YESTERDAY 1800 PRESENT OPERATlON= Drilling ahead. 24 Hour Footage 517 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SIN 1905644 INTERVAL IN OUT 1800 REASON PULLED CONDITION TIBIC JETS 7-11x5 FOOTAGE HOURS 517 5.81 LOW AVERAGE CURRENT AVG @ 2225 115.0 80.2 Mtr @ amps @ 1818 7.9 7.7 Klbs @ RPM @ psi 10 FL 7.3 Gels 3/9/10 CL- 1100 194 MaL 17.5 pH 9.5 Ca+ 40 CCI HIGH 973,6 @ 1801 @ 26 @ 2040 @ @ DEPTH: 2400' 44 PV 9 YP 6 SD tr OIL 13.2 0 HIGH LOW AVERAGE 172 @ 1986 2 @ 1839 59.2 TRIP GAS= 26u @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 40212 @ 1986 315 @ 1839 9776.1 CONNECTION GAS HIGH= 2u 0 @ 2317 0 @ 2317 0.0 AVG= 0 @ 2317 0 @ 2317 0.0 CURRENT 35u 0 @ 2317 0 @ 2317 0.0 CURRENT BACKGROUND/AVG 38u142u 0 @ 2317 0 @ 2317 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone, sand, coal, siltstone, sandstone, carbonaceous shale. PRESENT LITHOLOGY Sand 40%, sandstone 20%, claystone 30%, siltstone 1 0%, DAILY ACTlVllY SUMMARY Pulled up and made up 48 joints. Made up BHA, oriented motor to 78 degrees. Service rig, crown, draw WON, and top drive. Tripped into the hole to 925'. Pumped up survey at 925'. Ran in the hole to 1480' and pumped up a survey. Pressured tested casing to 2500 psi for 15 minutes. Ran in the hole tagging cement at 1705'. Drilled out cement, shoe, and 20 feet offormation to 1820'. Circulated and conditioned mud. Performed formation integrity test Drilled from 1820' to 2317'. Epoch Personel On Board= 4 Daily Cost $2721.00 Report by: Doug Ottke ~'. Unocal Nilnilchik Pearl #1 -,~ REPORT FOR Jim Benson DATE Feb 24,2002 TIME 00:00:00 CASING INFORMATION 9,625@1791' SURVEY DATA BIT INFORMATION NO. SIZE 2 6.5 TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,1 VIS FC V SOL MIIIID SUMMARY INTERVAL TOOLS TO GAS SUMMARY(unlts) ~TCH GAS mNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ~ ,r". DAILY WELLSITE REPORT ~ EPOCH DEPTH 3534 YESTERDAY 2318 24 Hour Footage 1216 PRESENT OPERATION= Drilling Ahead DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SIN 1905644 INTERVAL IN OUT 1800 HOURS 22.1 CONDITION T/BIC REASON PUllED JETS 7-11x5 FOOTAGE 1734 HIGH 281,0 @ 3183 @ 22 @ 2853 @ @ DEPTH: 2400' 44 PV 9 YP 6 SO tr OIL CURRENT AVG 113.0 LOW @ 3177 @ @ 3390 @ @ AVERAGE 97,8 4,4 ftIh r amps Klbs RPM psi 0 9,0 14.7 Cl- Ca+ FL MBl 7.3 17.5 Gels pH 3/9/10 9.5 1100 40 10 194 CCI HIGH LOW AVERAGE 461 @ 3103 14 @ 2891 59.7 TRIP GAS= @ @ WIPER GAS= 82u CHROMA TOGRAPHY(ppm) SURVEY= 175721 @ 3202 423 @ 3419 15366.2 CONNECTION GAS HIGH= 8u 0 @ 3534 0 @ 3534 0.0 AVG= 5u 0 @ 3534 0 @ 3534 0.0 CURRENT 82.2 0 @ 3534 0 @ 3534 0.0 CURRENT BACKGROUND/AVG 35/25 0 @ 3534 0 @ 3534 0.0 UTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY claystone. silstone, sand. sandstone, coal, carbonaceous material PRESENT LITHOLOGY 60% claystone, 30% sand, 10%slltstone DAILY ACTIVITY Drilled from 2317' to 2784'. Circulated and conditioned the mud. Pulled out of the hole from 2784' to 2555'. Back reamed to shoe. Serviced top drive. SUMMARY Tripped in the hole from 1780' to 2684'. Washed down to 2784', Drilled and slid from 2784' to 3534'. Epoch Personel On Board= 4 Daily Cost $2721.00 Report by: Doug Oltke r-. Unocal Nilnilchik Pearl #1 r--- REPORT FOR Jim Benson DATE Feb 24, 2002 TIME 23:29:21 CASING INFORMATION 9.625@1791' SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5 TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.8 VIS FC <21 SOL MIND SUMMARY INTERVAL TO TOOLS rGAS SUMMARY(unlts) ;CH GAS ~UTIlNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL ,~ i-"'-'", DAILY WELLSITE REPORT ~ EPOCH DEPTH 4803 YESTERDAY 3534 24 Hour Footage 1269 PRESENT OPERATlON= Drilling Ahead. DEPTH 3755.44 INCLINATION 0.35 AZIMUTH 331.40 VERTICAL DEPTH 3755.11 SIN 1905644 INTERVAL IN OUT 1800 CONDITION TIBIC REASON PULLED JETS 7-11x5 FOOTAGE 3046 HOURS 36.8 HIGH 242.5 @ 4164 7.2 @ 28 @ 4464 0 @ @ AVERAGE 108.2 ftIh r amps Klbs RPM psi CURRENT AVG 79.3 LOW @ 3811 @ @ 3707 @ @ 12.3 13.0 46 9 PV SO DEPTH: 4900 13 YP tr OIL CCI CL- Ca+ FL MBL Gels pH 3rT/8 9.5 800 60 6.0 20 10 /91 HIGH LOW AVERAGE 783 @ 4545 7 @ 3762 120.3 TRIP GAS= 58 @ @ WIPER GAS= 282 CHROMATOGRAPHY(ppm) SURVEY= 253101 @ 4485 512 @ 4716 22091.4 CONNECTION GAS HIGH= 6 276 @ 4010 1 @ 4717 7.5 AVG= 4 33 @ 4010 1 @ 4404 0.5 CURRENT 192 0 @ 4803 0 @ 4803 0.0 CURRENT BACKGROUNDIAVG 85/50 0 @ 4803 0 @ 4803 0.0 LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone, Siltstone, Sand, Coal. PRESENT LITHOLOGY 40% coal, 60% claystone DAILY ACTIVITY Drilled from 3540' to 3809'. Conditioned and circulated the mud. Took a survey. Pulled out of the hole from 3809' to 3610'. Back reamed from 3610' to SUMMARY 2135'. Tripped in the hole from 2135' to 3719'. Washed down to 3809'. Drilled ahead to present depth. Epoch Personel On Board= 4 Daily Cost $2721.00 Report by: Doug Ottke r--. Unocal Nilnilchlk Peart #1 .~ REPORT FOR Jim Benson DATE Feb 25,2002 TIME 23:40:00 CASING INFORMATION 9.625@1791' SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5 TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,8 VIS FC <21 SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY{units) r--, ';H GAS "'.) mNG GAS METHANE{C-1) ETHANE{C-2) PROPANE{C.3) BUTANE(C-4) PENTANE{C-ð) HYDROCARBON SHOWS INTERVAL ,,~ ,"" DAILY WELLSITE REPORT ~ EPOCH DEPTH 5312 YESTERDAY 4804 24 Hour Footage 508 PRESENT OPERATION.. Drimng Ahead DEPTH 5013.43 SIN 1905644 INCLINATION 0.63 INTERVAL JETS IN OUT FOOTAGE 1800 3578.5 HIGH LOW 400 @ 5308 10.4 @ 5312 @ @ 29 @ 5072 0 @ 5293 @ @ @ @ 6.8 AZIMUTH 359.52 VERTICAL DEPTH 5013.07 CONDITION T/B/C REASON PULLED HOURS 42.5 AVERAGE 133.4 CURRENT AVG 10.4 ftlhr amps Klbs RPM psi 6.8 46 9 PV SD DEPTH: 4900 13 YP tr OIL CCI 10 /91 Gels pH Cl- Ca+ FL MBL 317/8 9.5 800 60 6 20 HIGH lOW 1002 @ 5054 3 @ 5165 @ @ CHROMATOGRAPHY(ppm) 219676 @ 5054 539 @ 5165 15 @ 4865 1 @ 4924 @ @ @ @ @ @ llTHOlOGY/REMARKS AVERAGE 149,2 TRIP GAS= WIPER GAS= 289u SURVEY= CONNECTION GAS HIGH= 0 AVG:: CURRENT CURRENT BACKGROUND/AVG 60/60 32767.4 1,2 GAS DESCRIPTION From 4800 to 5000 predominantly finely Interbedded claystone, siltstone and sand altemating with beds of coal and carbonaceous shale. Between 5000 and 5050 a gas bearing sand was encountered (see show report #5). Then from 5050 to present depth lithology was siltier and sand was more consolidated, though this could also be a result of higher sample quality In the oil based mud. 30% claystone, 30% siltstone, 30% sandstone, 10% sand. LITHOLOGY PRESENT LITHOLOGY DAilY ACTIVI'TY Drilled to 5068'. Circulated and conditioned the mud. Took a survey and pulled out of the hole to 3742'. Bacl< reamed from 4850'to 3742'. Pumped out from SUMMARY 3742' to 1963'. Serviced crown and blocks. Added spacer spool to bell nipple. Pulled up 24 joints. Ran In the hole to 5068'. Circulated; changed over to oil based mud. Cleaned pits 1 and 3. Drilled from 5068' to present depth. EpOCh Personal On Board" 4 Daily Cost $2781.00 Report by: Doug OUke ,r-- ,~ ~ Unocal Nilnilchik DAJL Y WELLSITE REPORT ~ EPOCH Pearl #1 ,---- REPORT FOR Jim Benson DATE Feb 27,2002 TIME 00:00:00 DEPTH 6205 YESTERDAY 5312 24 Hour Footage 893 PRESENT OPERATlON= Drilling Ahead CASING INFORMATION 9.625@1791' BIT INFORMATION NO. SIZE 2 8.5 TYPE DP0622 SIN 1905644 JETS INTERVAL IN OUT 1800 FOOTAGE 4405 AZIMUTH VERTICAL DEPTH 327.65 CONDITION REASON HOURS TIBIC PULLED 59 AVERAGE CURRENT AVG 104.7 194.9 fl/hr amps 7.4 2U Klbs RPM psi SURVEY DATA DEPTH 6177,34 INCLINATION 1.40 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10,1 VIS FC 1<2 SOL 141 9.1 HIGH 348.4 @ 5335 @ 31 @ 5678 @ @ DEPTH: 6257 32 YP OIL LOW 3,2 @ 6126 @ 0 @ 5910 @ @ PV SO 28 84/16 FL MBL 91 Gels pH 24/32133 CL- Ca+ 24000 CCI MWD SUMMARY INTERVAL TOOLS TO ~S SUMMARY(units) TCH GAS \;UTTlNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 5375-5400 5876- 5902 HIGH LOW AVERAGE 410 @ 5385 11 @ 5927 132.9 TRIP GAS= @ @ WIPER GAS= 106u CHROMA TOGRAPHY(ppm) SURVEY= 70532 @ 5387 2066 @ 5927 22862.8 CONNECTION GAS HIGH= 0 32 @ 6167 1 @ 5927 9.5 AVG= 13 @ 6077 -1 @ 5892 0.7 CURRENT 69,5 0 @ 6205 -2 @ 5892 -0.0 CURRENT BACKGROUNDIAVG 45145 0 @ 6205 -2 @ 5892 -0.0 LITHOLOGY Show report #8: 5375-5400, show report #7: 5876-5902. lITHOLOGY/REMARKS GAS DESCRIPTION CT20SN20SS40ST20, isotube 410u Sandstone = medium gray to medium light gray; quartzose framework; fine to medium grained; well sorted; sample taken at 5387, 407,3u 137u rounded; high sphericity; soft to friable, occasionally moderately hard; clay matrix supported; thinly bedded to SN30SS60TU10, isotube sample laminated with abundant carbonaceous material, ash and silt, estimated poor to very poor intergranular porosity; taken at 5900, 137u no oil indicators. Sandstone = light whitish gray overall; fine to medium with occasional coarse grains; predominantly subround; mod to well sorted; moderate sphericity; 70%-80% quartz, 20%-30% lithics; 70%-80% consolidated with matrix; consolidated chips show complete Infilling with ash; abundant ash laminations; rare clay laminations; predominantly grain supported with common matrix supported; estimated very poor Intergranular porosity, Predominantly Inter)edded claystone and silstone from 5312 to 5375 where a 25 foot thlnck gas bearing unit, mostly consolidated sandstone, was enCountered (see show report #8). The clays and siltstones where sandier to approximately 5500 interbedded with occasional gas bearing coals. 5500 to 5560 was predominantly sandstone with claystone; 5560 to 5740 was predominantly claystone and siltstone with abundant sandstone. 5740 to 5876 was claystone with several coal beds, At 5876 the second gas bearing sandstone unit of the past 24 hours was encountered for 26 feet (see show report #7). 5902 to 6145 was predominantly claystone with occasional coal beds and sandstone. From 6165 to 6180 a thick coal bed was encountered amidst mostly claystone and siltstone with trace unconsolidated sand, Periodic very thinly bedded 'bones' encountered after 5540 slowing rop markedly. PRESENT LITHOLOGY 60% claystone, 20% siltstone. 20% sand. DAILY ACTIVITY SUMMARY Drilled to 6137. Circulated bottoms up. VViper tripped to 4744. Pulled up 42 joints of drill pipe, and ran them into the hole. Drilled to 6205, Epoch Personel On Board" 4 Daily Cost $2781.00 ~ Report by: Doug OUke ~ Unocal Nilnllchik ~ DAILY WELLSITE REPORT g EPOCH Pearl #1 /~ REPORT FOR Harold Fahrlender DATE Feb 28,2002 TIME 00:00:00 DEPTH 6912 YESTERDAY 6206 24 Hour Footage 706 CASING INFORMATION 9.625@1721' SURVEY DATA DEPTH 6629.97 INCLINATION 1.51 BIT INFORMATION NO. SIZE 2 8.5 SIN 1905644 INTERVAL JETS IN OUT 1800 HIGH 360.5 @ 6900 2.7 @ 96 @ 6629 0 @ @ DEPTH: 6910 PV 31 YP SD OIL TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.1 VIS FC 1<2 SOL 126 9.1 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) .~ ~H GAS - -' fTlNG GAS PRESENT OPERATION= Drilling Ahead AZIMUTH VERTICAL DEPTH 324.09 6829.27 CONDITION REASON FOOTAGE HOURS T/BIC PULLED 5112 77.5 LOW AVERAGE CURRENT AVG @ 6678 72.7 12.3 ftlhr @ amps @ 6583 11.3 10.6 Klbs @ RPM @ psi 19 84/16 FL MaL Gels pH CL- Ca+ CCI 21/29 5 30 HIGH LOW AVERAGE 391 @ 6837 12 @ 6628 130.5 TRIP GAS= 0 @ 6912 0 @ 6912 0.0 WIPER GAS: CHROMATOGRAPHY(ppm) SURVEY= 74955 @ 6353 2232 @ 6628 23740.9 CONNECTION GAS HIGH= 0 37 @ 6788 1 @ 6703 7.4 AVG= 16 @ 6837 1 @ 6875 1.5 CURRENT 62.6 0 @ 6912 0 @ 6912 0.0 CURRENT BACKGROUND/AVG 110/110 0 @ 6912 0 @ 6912 0.0 METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5} HYDROCARBON SHOWS INTERVAL None LlTHOLOGY/REMARKS lsotube sample C-3162 taken at 6802' 108u lsotube sample C-3163 taken at 6894' 117u lsotube sample C-3164 taken at 6904' 165u GAS DESCRIPTION From 6200 to 6300 predominantly interbedded claystone and siltstone got sandier. Between 6300 and 6400 several thick coal beds were encountered amidst claystone, siltstone lithology. From 6400 to 6800 mostly claystone with siltstone, sandstone and someash and several thin coal beds was encountered. At 6800 and 6900 two sand channels were sampled for gas (see lsotubes C-3162, 3163, and 3164), however, gas was not high enough to justify show qualification. Mostly sandy claystone and siltstone to midnight depth. 40% Claystone, 30% siltstone, 20% sandstone, 10% sand LITHOLOGY PRESENT LITHOLOGY DAILY ACTNITY SUMMARY Rotated and slid from 6204 to 6628. Pulled out of the hole to 6415 to change out aCtuator on top drive. Ran in the hole and continued drilling to 6912. Epoch Personel On Board= 4 Daily Cost $2781.00 Report by: Doug Ottke ,r-', ~ ~ Unocal Nilnilchik DAILY WELLSITE REPORT ~ EPOCH Peart #1 REPORT FOR Harold Fahrtender DATE Mar 1, 2002 TIME 00:00:00 DEPTH 7255 YESTERDAY 6912 24 Hour Footage 343 PRESENT OPERATION= Rigging up to RIH for core. CASING INFORMATION 9.625@1721' BIT INFORMATION NO. SIZE 2 8.5 TYPE DP0622 SIN 1905644 JETS 7x10 INTERVAL IN OUT 1800 7255 FOOTAGE 5455 AZIMUTH VERTICAL DEPTH 328.95 7203,70 CONDITION REASON HOURS T/BIC PULLED 86 core pl AVERAGE CURRENT AVG 50.1 50.7 ftIh r amps 10.0 23.9 Klbs RPM psi SURVEY DATA DEPTH 7204.54 INCLINATION 1.58 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.1 VIS FC 1<2 SOL 126 9.1 HIGH 199.1 @ 7013 @ 35 @ 7248 @ @ DEPTH: 6910 31 YP OIL LOW 3.2 @ 7235 @ 0 @ 6987 @ @ PV SD 19 84/16 FL MBL 5 Gels pH 21/29/30 CL- Ca+ 27000 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units} ~ TCH GAS ...l.ITTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 7073'-7106'1 7125'-7160' HIGH LOW AVERAGE 275 @ 7135 8 @ 7058 129.4 TRIP GAS: 0 @ 7255 0 @ 7255 0.0 WIPER GAS: CHROMA TOGRAPHY(ppm} SURVEY: 50794 @ 7135 1504 @ 7058 23219.4 CONNECTION GAS HIGH: 0 40 @ 7117 1 @ 7204 17.3 AVG= 18 @ 6912 1 @ 7235 3.4 CURRENT 0 @ 7255 0 @ 7255 0.0 CURRENT BACKGROUND/AVG 96 0 @ 7255 0 @ 7255 0.0 Show report #87073'-7106'1 Show report #9 7125'-7160' LlTHOLOGY/REMARKS GAS lsotube Samples C-3166 taken from Max 7102' 202u/ C-3167 taken from 7133' gas 274u/ C-3168 taken from 7155' 235u1 203u1 c-3169 taken from 7193' 200u Max gas 275u DESCRIPTION Show rpt #8 SANDSTONE: V L T GY TO WHSH GY; F TO MED W OCC V F AND RR CRS; ANG TO OCC SBRND; P TO MOD SRTG; LOW TO MOD SPHER; 70%-80% QTZ, 20%-30% LlTHICS; 60%-80% CONS; ABNDT DECRSNG TO COM CLAY ASH MTX; GRN SUPORTED W RR MTX SUPPORT; COM LAMS OF ASH; RR CARB STREAKS; EST PRED P INTGR PORO; NO OIL INDICATORS.lShow rpt #9 SANDSTONE = L T GY TO WHSH GY OVERALL: V F TO MED W RR CRS GRNS; MOD SRTG W acc WELL SRTD F AND V F LAMS; SBANG TO SBRND; MOD SPHER; 70% QTZ, 30%LlTHIC; COM CLAY/ASH MTX GRDG TO OCC IP; ABNDT LAMS OF ASH IN LWR SECT; PORO PRED INFIL W MTX W OCC OPEN PORO; GRDS TO SL TST IP; EST V P W OCC FR INTGR PORO; NO 0 SHOWS. LITHOLOGY From 6900 to 7000 predominantly claystone with secondary siltstone and sand and thin coal beds encountered. At 7000 and 7100 thick sand units were sampled see isotubes C-3165, 3166 and for the latter show report #8. From 7100 to core point depth claystone/siltstone interbedded lithology was broken by thin coal beds and sand channels from 7125 to 7160 (see show report #9) and 7225 to 7255. 60% Claystone, 20% sandstone, 10% siltstone, 10% sand. PRESENT LITHOLOGY DAILY ACTIVITY Drilled to 7225. Rig ran low of fuel, pulled off bottom to wait for fuel truck. Drilled to 7257, Circulated bottoms up. Pulled out of the hole. Stood back BHA. SUMMARY Pressured tested BOP's to 3000 psi. Performed koomey test Serviced rig. Epoch Personel On Board= 4 Daily Cost $2781.00 Report by: Doug Ottke /'"""~, Unocal ~ .~ DAILY WELLSITE REPORT U EPOCH DEPTH INCLINATION 7204.54 1.58 INTERVAL SIN JETS IN OUT 1905644 7x10 1800 7255 Nílílchlk Pearl #1 REPORT FOR Harold Fahrlender DATE Mar 02, 2002 TIME 00:00:00 CASING INFORMATION 9.625@1721' SURVEY DATA BIT INFORMATION NO, SIZE 2 8.5 TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.2 VIS FC 1<2 SOL DEPTH 7342 YESTERDAY 7255 24 Hour Footage 87 HIGH 67.1 @ 7290 @ 36 @ 7267 @ @ DEPTH: 7257 137 PV 31 YP 9.2 SD OIL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(unit&) ~ . TCH GAS -UTTING GAS 152 0 HIGH @ @ METHANE(C-1) 27210 @ ETHANE(C-2) 12 @ PROPANE(C-3) 7 @ BUTANE(C-4) 0 @ PENTANE(C-5) 0 @ HYDROCARBON Show report #107285'07315' SHOWS INTERVAL LlTHOLOGY/REMARKS 7285-7315 B-3170 taken from 7288 C-3171 taken from 7295 C-3172 taken from 7327 c- 3173 taken from 7336 LOW 7293 26 @ 7268 7342 0 @ 7342 CHROMA TOGRAPHY(ppm) 7335 4797 @ 7268 7255 1 @ 7260 7255 1 @ 7259 7342 0 @ 7342 7342 0 @ 7342 PRESENT OPERATION= Pulling out of the hole. 0.5 AZIMUTH VERTICAL DEPTH 328.95 7203.70 CONDITION REASON FOOTAGE HOURS TIBIC PULLED 5455 86 corept. LOW AVERAGE CURRENT AVG @ 7264 17.4 6.7 ftIh r @ amps @ 7258 16.9 26.8 Klbs @ RPM @ psi 3 18 73 FL MBL CCI Gels pH 22128/31 CL- Ca+ 5 31000 AVERAGE 70.2 0.0 TRIP GAS= 311 WIPER GAS= SURVEY= CONNECTION GAS HIGH= 0 AVG= CURRENT CURRENT BACKGROUND/AVG 95 12532.3 0.3 0.2 0.0 0.0 GAS DESCRIPTION max SANDSTONE = MED L T GY TO VY L T GY; V F TO F GRN W oce MED AND CRS; SUBANG TO 152 SUBRND; P TO MOD SRTG; LOW TO MOD SPHER; 80% QTZ, 20% LlTHleS; 80% CONS; ABDNT CLAY/ASH MTX; PREDOM GRN W oce MTX SUPPORT; COM lAMS ASH AND CARB MAT; EST P W OCC FR INTGR PORO; FRIABLE TO FIRM FRIABLE; NO OIL INDICATORS. LITHOLOGY PRESENT LITHOLOGY From 7250 to 7285 predominantly claystone was encountered. From 7285 to 7315 a thick sandstone unit was cored (see show report #1 0). Following the sandstone claystone and a coal bed were encountered before midnight depth. 40% coal, 30% siltstone, 20% claystone, 10% carbonaceou& shale. DAILY ACTNITY Pulled up core barrel assembly, BHA. HWDP. Tripped into the hole to the show. Cut and slipped drill line. Serviced top drive. Tripped in the hole to SUMMARY bottom. Circulated hole clean. Cored from 7257 to 7341. Circulated bottoms up. Epoch Personal On Board= 4 Daily Cost $2761.00 Report by: Doug Ottke ~~. .'-""" .............. Unocal Nllnilchik DAILY WELLSITE REPORT ~ EPOCH Pearl #1 REPORT FOR Harold Fahrlender DATE Mar03,2002 TIME 00:00:00 DEPTH 7417 YESTERDAY 7343 24 Hour Footage 74 PRESENT OPERATION= Drilling Ahead. CASING INFORMATION 9.625@1721' SURVEY DATA DEPTH 7204.54 INCLINATION 1.58 BIT INFORMATION NO. SIZE 3 8.5 TYPE DP0622 SIN 1905644 JETS 7x10 INTERVAL IN OUT 7342 FOOTAGE 101 AZIMUTH VERTICAL DEPTH 328.95 7203.70 CONDITION REASON HOURS T/BIC PULLED 5,3 AVERAGE CURRENT AVG 52.1 7.9 ftIhr amps 16.3 17.3 Klbs RPM psi DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.2 VIS FC 1<2 SOL HIGH 163.4 @ 7364 @ 52 @ 7385 @ @ DEPTH: 7257 PV 31 YP SD OIL LOW 2.3 @ 7385 @ 9 @ 7392 @ @ 137 9.2 18 73 FL MBL 5 Gels pH 22128/31 CL- Ca+ 31000 eci MOO SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) ~ , 1TCH GAS ';UTTING GAS METHANE(C-1) ETHANE{C-2) PROPANE{C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 149 @ 7377 15 @ 7417 52.8 0 @ 7417 0 @ 7417 0.0 CHROMA TOGRAPHY(ppm) 27682 @ 7377 5325 @ 7379 6689.5 0 @ 7417 0 @ 7417 0.0 0 @ 7417 0 @ 7417 0.0 0 @ 7417 0 @ 7417 0.0 0 @ 7417 0 @ 7417 0.0 LlTHOLOGY/REMARKS TRIP GAS= 58 WIPER GAS= SURVEY= CONNECTION GAS HIGH= 0 AVG= CURRENT CURRENT BACKGROUND/AVG 14 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Mostly claystone/siltstone interbedded lithology with minor amounts of sandstone and several thin beds of coal was encountered from 7350 to midnight depth. 60% Claystone, 40% siltstone D Y C Circulated bottoms up. monitored well. Pumped dry job. Pulled out of the hole slowly to prevent swabbing. Monitored well at shoe. Handled BHA. Laid down S~~~R~IVITY inner core and barrel. Laid down mud motor assembly. Pulled up rotating drilling assembly. Made up BHA. Ran in the hole to 3661. Filled drill pipe and broke circulation. Pulled up 30 joints of drill pipe. Ran in the hole. Reamed to 7341. Drilled to 7417. Epoch Personal On Board= 4 Daily Cost $2781.00 Report by: Doug Ottke ~ Unocal Nilnilckik Pearl #1 ~- REPORT FOR Harold Farhlender DATE Mar04,2002 TIME 00:00:00 CASING INFORMATION 9,625@1721' SURVEY DATA BIT INFORMATION NO, SIZE 3 8.5 TYPE DP0622 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.1 VIS FC 1<2 SOL MIND SUMMARY INTERVAL TOOLS TO GAS SUMMARY{units) --~ 'fCH GAS ",UTTING GAS METHANE{C-1) ETHANE{C-2) PROPANE{C-3) BUTANE{C-4) PENTANE{C-5) HYDROCARBON SHOWS INTERVAL /~', ,..........,,\ DAILY WELLSITE REPORT g EPOCH HIGH LOW AVERAGE 228 @ 7617 15 @ 7417 53.2 0 @ 7761 0 @ 7761 0.0 CHROMATOGRAPHY{ppm) 41657 @ 7617 2558 @ 7452 9103.9 105 @ 7672 1 @ 7602 16.8 49 @ 7672 1 @ 7641 5.0 0 @ 7761 0 @ 7761 0.0 0 @ 7761 0 @ 7761 0.0 LITHOLOGY/REMARKS lsotube sample C-3174 taken at 7430' 119u DEPTH 7761 YESTERDAY 7417 24 Hour Footage 344 DEPTH 7204,54 INCLINATION 1.58 PRESENT OPERATION= Drilling ahead. 1.4 AZIMUTH VERTICAL DEPTH 328.95 7203.70 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 419 27.3 LOW AVERAGE CURRENT AVG @ 7725 36.6 14.9 ftlhr @ amps @ 7463 15.0 11.5 Klbs @ RPM @ psi SIN 1905644 JETS 7-11 INTERVAL IN OUT 7342 5 15 75 Gels pH CCI HIGH 161.7 @ 7424 @ 33 @ 7479 @ @ DEPTH: 7419 126 PV 28 YP 9.2 SD OIL FL MBL 19/26/30 CL- Ca+ 5 31000 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= 0 AVG= CURRENT CURRENT BACKGROUND/AVG 36 GAS DESCRIPTION At 7430 predominantly claystone/siltstone interbedded lithology chnaged to a sand channel (see isotube sample C-3174). From 7430 to 7675 sandy siltstone/claystone mixed with thin coal beds. At 7675 sand became predominant and tumed coarser with conglomerate common. Conglomeratic sand petered out at 7755 where a coal bed was encountered before midnight depth. 30% sandstone. 20% sand, 20% siltstone, 20% claystone, 10% carbonaceous shale. LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled from 7417' to 7761'. Epoch Personel On Board= 4 Daily Cost $2781.00 Report by: Doug Ottke ~- /-- r---\ Unocal Nilnilchik DAILY WELLSITE REPORT g EPOCH /~ Pearl #1 REPORT FOR Harold Fahrlender DATE Mar 05,2002 TIME 00:00:00 DEPTH 8000 YESTERDAY 7762 24 Hour Footage 238 PRESENT OPERATION= Pulling out of the hole. CASING INFORMATION 9.625@1721' SURVEY DATA DEPTH 7204.54 INCLINATION AZIMUTH VERTICAL DEPTH 1.58 328.95 7203.70 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7-11 7342 8002 660 39.3 TO reached HIGH LOW AVERAGE CURRENT AVG 124.6 @ 7901 1.5 @ 7869 34.4 44.7 ftlhr @ @ amps 65 @ 7808 @ 7807 14.3 9.2 Klbs @ @ RPM @ @ psi DEPTH: 7700 24 YP 15 FL 5 Gels 11/19/28 CL- 29000 OIL 75 MBL pH Ca+ CCI BIT INFORMATION NO. SIZE 3 8.5 TYPE DP0622 SIN 1905644 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.1 VIS FC ~ SOL 106 9.2 PV SD MWD SUMMARY INTERVAL TOOLS TO ~GAS SUMMARY(units) , ITCH GAS ';UTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW 205 @ 7821 15 @ 7866 @ @ CHROMATOGRAPHY(ppm) 53456 @ 7803 2117 @ 7866 73 @ 7803 6 @ 7929 20 @ 7800 1 @ 7967 a @ 8000 0 @ 8000 a @ 8000 0 @ 8000 LITHOLOG~REMARKS lsotube sample C-3175 taken at 7982' 101u AVERAGE 73.2 15061.4 29.3 6.3 0.0 0.0 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= 0 AVG= CURRENT CURRENT BACKGROUND/AVG 16 GAS DESCRIPTION LITHOLOGY From 7765 to 7800 a thick coal bed was encountered. From 7800 to 7845 a sand channel was drilled. To 7955 interbedded claystone/siltstone lithology with several thin beds of coal was encountered. From 7955 to td at 8000 a sandstone/conglomeratic sand with large amounts of siltstone and claystone was drilled and isotube sample C-3175 was taken at 7982. 40% Siltstone, 30% claystone, 10% sandstone, 10% conglomeratic sand, 10% tuff PRESENT LITHOLOGY DAILY ACTIVITY Drilled to 7808. Pumped dry job. Pulled out of the hole to 7110. Worked on top drive replacing the IBOP valve and accuator. Tripped into the hole and SUMMARY drilled to 7862. Worked on the top drive. Drilled to TD at 8000. Epoch Personal On Board= 4 Daily Cost $2781.00 Report by: Doug Ottke ~ ,-.. ~ ~~~~E lliF ~~!Æ~~«~ j AI,ASKA OIL AND GAS CONSERVATION COMMISSION I Dan Williamson Drilling Manager Unocal PO Box 196247 Anchorage AK 99519-6247 TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Pearl #1 Unocal Permit No: 202-011 Sur. Loc. 1568' FNL, 1968' FWL, Sec. 24, T01S, R14W, SM AK Btmhole Loc. 1568' FNL, 1968' FWL, Sec. 24, T01S, R14W, SM AK Dear Mr. Williamson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are fIrst caught and 10' sample intervals through target zones. The request for the exception to 20 AAC 25.035(c)(1)(B) to drill 12-114" hole with 12" diverter line is granted. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the \ test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ . ~vÁ '. . Ð/ Cammy chsli TaYIOH Chair BY ORDER OF THE COMMISSION DATED this 31st day of January, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~ --- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Union Oil Company of California ("Unocal") for an order granting an exception to the spacing requirements of 20 MC 25.055(a)(2) to provide for the drilling and testing of the South Ninilchik Drilling Pad Pearl-1 exploratory well to an undefined gas pool. ) Conservation Order No. 463 ) ) Pearl-1 Well ) Exploratory Well ) ) January 15,2002 IT APPEARING THAT: 1. Union Oil Company of California ("Unocal") by letter dated September 24, 2001, requested an exception to the well spacing provisions of 20 MC 25.055(a)(2). The exception would allow the proposed Pearl-1 exploratory well to be drilled and test produced for gas at a bottomhole location within 1500 feet of a property line. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on October 4,2001, pursuant to 20 MC 25.540. 3. The Commission did not receive a protest. 4. Unoca1 provided additional information to the Commission bye-mail on January 10, 2002. FIND IN GS : 1) The Pearl-l well would be drilled as a straight hole from surface to total depth. Surface location will be 1970.40' FWL, 1569.50' FNL, TIS, RI4W, Section 24. 2) Unocal notified all offset owners, landowners, and operators of all wells within 3,000 feet ofthe Pearl-1 well. 3) There are no other completed wells or wells capable of producing gas within the same governmental quarter section as the Pearl-l Well, but there is an abandoned Mobil well within the same governmental quarter section. 4) Unocal represents that after thorough site assessment and wetlands delineation review of the prior approved "Albright-1 Well" it determined that the Pearl-1 is more suitably situated to meet the present needs of its exploration program .--- Conservation Order No. 46j Janaury 15,2002 Page 2 .'-"" because (1) pennitting setbacks for the Albright-1 site put at risk existing contractual obligations with Enstar; (2) 2D seismic interpretations disproved any increased geologic risk by moving south of the Albright-l location; and (3) Marathon's objections regarding correlative rights at the Albright hearing forshadowed additional delays and threatened the possibility of an adverse AOGCC ruling diluting Unocal's working interest in South Nini1chik. 5) There is no location on the Unocallease where an exploratory gas well could be open to test production 1,500 or more feet away from a property line. CONCLUSIONS: 1) An exception to 20 AAC 25.055(a)(2) is necessary to allow drilling and test production of the Pearl-l exploratory gas well. 2) Granting a spacing exception to allow drilling and reasonable test production of the Pearl-1 exploratory well will not result in waste or jeopardize the correlative rights of adjoining or nearby owners. 3) Granting this spacing exception is reasonably necessary to provide Unocal with a timely opportunity to establish the volume of gas reserves it owns in the general area. 4) No other location on Unocal's lease would enable test production for gas in accordance with the spacing rules under 20 AAC 25.055. 5) Before regular production is pennitted from the Pearl-1 well, the Commission must take such action as will offset any advantage which the person securing the exception may have over the other producers by reason of the drilling of the well as an exception, and so that drainage from development units to the tract with respect to which the exception is granted will be prevented or minimized. AS 31.05.1O0(b). NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(2) for the purpose of drilling and testing the Pearl-1 well is approved under the following conditions. 1) The Pearl-l exploratory gas well must be logged and tested to detennine the well's potential to produce hydrocarbons. /~ ,-... Conservation Order No. 46:' Janaury 15,2002 Page 3 2) The operator must obtain the Commission's prior approval of a testing program for the well. 3) This order does not authorize regular production. DONE at Anchorage, Alaska and dated January 15, 2002. ~\~o~~~ ( ~ IE} \ f.' I 1M I & ~¡~~~~[~~~ ).i~ J " ""ø.¡ ~ iiCíN co \ AS 31.05.08 . s that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23Td day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the fmal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., lOth day after the application for rehearing was filed). &.ßV\A'~ âtJ1;~ k~,/ Cammy O~hsli Taylor, Chai{) Alaska Oil and Gas Conservation Commission ~MI ~~ Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission ,.!III UNOCAL8 So utt"'"'"'tnilchik Pearl Well No.1 Permit to Drill ¡JejA I[ ¿«to z- 1r\/3 \ -Cd-- J1.4 ~ 1/3-11 02- PERMIT TO DRILL FORM 10-401 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: s.~ .1£1 wmOm,," Redrill: Deepen: 1b. Type of well Service: 1a. Type of work Drill: X Re-Entry: 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska, 99519-6247 4. Location of well at surface 1568' FNL, 1968' FWL, Section 24, T 01 S, R14W, SM AK At top of productive interval 1568' FNL, 1968' FWL, Section 24, T 01 S, R14W, SM AK At total depth 1568' FNL, 1968' FWL, Section 24, T 01 S, R14W, SM AK 12. Distance to nearest 13. Distance to nearest well section line 1568' F N L feet 200 Feet 16. To be completed for deviated wells Kickoff depth: N/A feet Maximum hole angle: N/A 18. Casing program size Casing 13-3/8" 9-5/8" Hole Specifications Grade Coupling K-55 Welded L-80 Buttress L-80 Buttress 12-1/4" 8-1/2" 7" Weight 61 47 29 19. To be completed for Redrill, Re-entry, and Deepen Operations. Stratigraphic Test: Development Oil: Single Zone: Multiple Zone: X 10. Field and Pool South Ninilchik Prospect Exploratory: X Developement Gas: 5. Datum Elevation (OF or KB) 225.8' SURVEY feet 6. Property Designation Private Land - See Location 7. Unit or property Name Unocal Lease # 1030340 8. Well number No.1 9. Approximate spud date 02/7 Æee+- d-.CC;}... 14. Number of acres in property 11. Type Bond (see 20 AAC25.025) Statewide Blanket Bond Number U - 629269 Amount $200,000 15. Proposed depth (MDandTVD) 20 8,250' MOl 8,250' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maxirrumsurface 2885 psigAttotaldepth(TVD) 3710 psig Settinç Depth Length 80' 1800' 8250' Top Bottom Quantity of cement MD TVD MD TVD (include stage data) 0' O' 80' 80' N/A 0' 0' ~ 1800' Lead 280 sxs, Tail 202 sxs 0' 0' (!250' 8250' 100 Lead, 480 Tail, If-C),>, þI./GÅ RECEIVED JAN 0 7 2002 Alaska Oil & Gas COOs Co " Anchoragè mmlSSlOn Diverter Sketch: X Seabed report: Drilling program: X 20 AAC 25.050 requirements: X c:~J2 ~~ ~~y vy Mg ¥'. Permit Number - '0 /1 I API num~~ '2 ~ ' ;oq- _J Approval date \:::1\ dì I See cover let~er 2.b:2.. 50- f....x.) 2. 0 S , I ða V)\ u ~ for other requirements Conditions of approval Samples required: [] Yes [)(T No Mud log required: [] Yes M. No HYdrOge"n, SUlfid, e measures [] Yes , ["J No , ,Di,rectional survey required [] Yes Þ<J N°:I:..P1c.lfF1<- hdn", $u./îÆ.L( Re¡¿v'~ Required working..e.ressure fqr BOPE [] 2M; [] 3M; [] 5M; [] 10M; [] 15M ,\: ---J r) vJ4A Other: 't€l;.t rsoPE f<c> 3°, 00 p~. W~e II" ()~ ,?oAAL '2.5, O~S (ç.J¿¡)Cß)(~titl/&e! t. ý t z..11 cliï',fÌ-ed ÎI\..Q. .- Original Signed B by order of , ( Q..' 'J '1 Approved by C V Commissioner the Commission Date: \ ':')} {~~ ammy Oechsli Pennit to Drill page 3 of 47 Date)/'7/01 FW: AS PER OUR CONVERSATION, PLEASE FO~ TO SCHLUMBERGER ~ Subject: FW: AS PER OUR CONVERSATION, PLEASE FORWARD TO SCHLUMBERGER Date: Tue, 29 Jan 2002 18:31:57 -0800 From: "Mosley, Jim I" <mosleyj@unocal.com> To: "'Steve - davies@admin.state.ak.us'" <Steve - davies@admin.state.ak.us> CC: "'Tom_Maunder@admin.state.ak.us'" <Tom_Maunder@admin.state.ak.us> Tom, Steve, Here is the proposed logging program. It is subject to hole condition changes. But the intent is to run the logs shown as required and planned. The optional logs will probably not be run. Jim M. > PROPOSED PEARL # 1 > ELECTRIC LOGGING PROGRAM > > The following constitutes the proposed geological and evaluation logging > program for the subject well. Some of the logs are contingent upon tool > availability, hole conditions encountered, and geologic results. > > 12-1/4" SURFACE HOLE FROM +or- 1800' TO SHOE OF 13-3/8" @ +or- 100' > OPEN HOLE LOGS > REQUIRED LOG Platform Express -AIT/SP/GR/ DEN/NEU/CALIPER > OPTIONAL LOG FMI/Caliper - Two arm or better > > 8-1/2" PRODUCTION HOLE FROM + or - 8250' TO > OPEN HOLE LOGS > PLANNED LOG > PLANNED LOG > PLANNED LOG > PLANNED LOG SHOE OF 9-5/8" @ + or - 1800' MWD With DIRC/GR/RES TO CORE POINT PLATFORM EXPRESS AIT/SP/GR/DEN/NEU/DIPOLE SONIC CMR/HNGS/ECS/CALIPER CHECK SHOT SURVEY NOTE CAN BE RUN INSIDE CASING > > CASED HOLE LOGS FROM PBTD TO TOP OF 7" CEMENT > PLANNED LOG GR/CCL > OPTIONAL LOG(s) USIT/CBT/GR/CCL > PLANNED LOG RST > > OTHER GEOLOGIC EVALUATION > MUD LOGGING > Mud logging will be conducted from the shoe of the 13-3/8" @ 100' until > total depth. > > GAS DETECTION > Gas detectors will be functional and running prior to spud. > > CORING > A whole core is optionally anticipated to be taken in one of the > 6200-6500' DEPTH TYONEK gas bearing sands. Hole conditions and geologic > results will determine whether the whole core is taken. The ability to > correlate will be enhanced with LWD GR/RES tools. > > > Jim Mosley > Advising Drilling Engineer > Unocal Alaska > Union Oil Company of California > 909 W. 9th Ave. P.O. Box 196247 > Anchorage Alaska 99519-6247 > Office 907-263-7679 > Cell 907-351-8639 > Home 907-694-4170 > Fax 907-263-7884 > EMAIL Mosleyj@Unocal.com 10f2 1/29/2002 6:28 PM DEC-21-2001 FRI 06:22 PM MCLANE CONSULTING GROUP ~ FAX NO. 9072833265 ~ -~'13 --- - - ,.---- ..-. 23'. ""2-~:-'" """""-""""--..---.---- '.. P, 02 , I ~ Z ~D L 11-11"'$ '\.'-"'\'\ ~ -,,".. OF Ai . '. -- .. ",=--" '~"""""',::<I& I, :: ~~" ~".:r " :: *~"'49 Il:l J\\ "!* ~ ,.,.. , .. .. .. . , . .. .. .. . .. . , .. .. , .. .. .. , I' ~. ~ ~ "" ,¡' ... . .. , , .. I .. , . , .. .. , .. , .. .. . .. , .. 116 l ~~ ~.M. SCOTT McLANE': fl -- .1 ' " .. "'- Î >J',:., ". 4928-$ ..' -~ - I~ ~1;'~ ", ,.' 0/ - f' ì () ~ ""...." . ' ..~ .:;r I " Xb;.'rss ION"\. \. ,-'" '\\\""~ ~.. "- -_.. -.._._...__.._~~~~-!~~----- ~... ""-"" '-.."'-0- """~~ '..... ~ 'I"".... -.~..¿iC:C~ .~---. ~....::...S$ -- -"""-'?? .<:1 D ASßUIL T SU~FACE WELL LOCATION PEA~L NO, I ASP ZONE 4 NAD 21 6RID N: 2224~12.'4:, <'IRID E: 2ØE>8E>1.496 LATITUDE, 6Ø'Ø4'4&.68Ø" N LoNGITUDE: 1&1'~6'~8.929" W ELEVATION: 22&.8' NOTF:S: I. BAßi5 Or- COORDINATES: NGS STATION "V82" (ADOT) NAP 21 2. DAB!!? Or- ELEvATION, NGSeM VF:-2 N6Vr) 2<:) . :3, f;>f~c.1ÏON LINE OFFSETS DERIvED F~~OI'" TIES TO SURVEY MONUMENTS ALON(:r NOF<Tf.J BOUNDARY OF 5r~CTION 24 TIS RI4W SM FOUND THIS ðURVr:Y SCALE 1 inch == 100 ft. 0 100 ~ -. ",.. --.---,..---- - APPUCAN'r= ASBUIL T PEARl.. NO. 1 SURFACE LOCATION :UNDCALe Sheet 1 of 1 OFFSETS 1968' FWL SECTION 24 1568' FNL T15 R14W SM AK 909 W. 9th Avenue Anchorage, AK 9£1519-7685 McLANE Dwg: 014003 I Date: 12/21/01 f.ngincc"s, Survey"" and Planners P.O, Box 4tH! Soldolno. AK Y!J669 -..-.---'- ..~" ..J Z U- (¡;) ~ !!:! 9 SECTION 24 TOWNS~IF I 50UT~ RANGE 14 WEST SEWARD MERIDIAN ALASKA 150 1 200 ! RESERVE PIT DATA: 1, CAPACITY:. 24,000+ BBlS 2. ADDITIONAL 2' OVERBOARD 3, LINER: SIEMENS XR-5 8130 FIGURE: 1 . ".' .,.", ""-.." 195000 , 202,500 r"o, 225000 0 ~ ~~ N N 35 36 + 3 10 I\) I\) ~ 0 0 0 0 0 0 ~- N N + 15 18 '1 I\) It> I\) + I\) + --.. ~ 0 TJ-°1SQ1 NINILCHIK R 1 21 ~ + I\) -0 0 8 28 0 f6 1'--- + N ~~14W 22 . 8 0 o- N N N + 27 0 f6 N- .... N N ---n + 33 + I\) I\) ..... -I\) g: 0 0 2000 4C 00 Feet 2 t I ---. ~__l______---______mm_m_m_!;_m______m__- -------______m_4__- 3 200( ~ Lease Legend § Fee I..- 51010_-_0720-011> UnivetOl.. L- ........ _tit l..- I')- - -.' AURORA DIll MARATI«JH ~ MARATHON aJ UNOCAl ~ ~ MARATHON D UNOCAl [2]-- N D -- [Z] UNOCAl - PHUPS ~ UNOCAl +- Unocal Proposed Pearl-1 Location Map Showing Offset Wells and Leases I\) I\) 0 -(11 0 .0 -0 195000 202500 210000 217500 , 225000 g 0 0 '" N N ~ !5 § 0 0 '" .... ¡::¡ 0 0 :¡¡ N N N 0 0 '" ¡::: ¡::: Unocal Proposed Location Pearl No.1 Township 1 S, Range 14W, Section 24 500 N A 0 500 Feet .... Alaska Stateplane Zone 4, NAD27 NOTE: Background 1m agery is IKONOS, Sum mer 2000. I 207500 . 202500 § 0 '" N N /- 0 0 on .... N N N I '...--: I I I ~b I '- I --- --. ) , I I I -~ \ ' ---L - -- § \ r , i J I I f. .- - ..-" t-- '\ -- 1/' l' 'WI' I '" --, " ). ¡ì ì,.- ~ ;1 -t;: 0 0 '" '" '" -'" '" 0 0 /' / r ~ " '\ I ----,/ 0 0 on N- N N N Unocal Proposed Location Pearl No.1 Township 1S, Range 14W, Section 24 N Â 500 0 500 Feet .... Alaska Stateplane Zone 4, NAD27 NOTE: Background im agery Is USGS 1:25000 DRG. I 202500 I 205000 I 207500 202,000 204000 ..--. ) ,d Exhibit A: (see Exhibit A-1 for associated TRACT information) 20epOO ---- 208000 ß'~-- 0 0 ~-+ ('II ('II ('II + I\) I\) I\) -(XI 0 0 0 0 0 ~-+ ('II ('II ('II I\) '" '" en 8 0 '" I\) '" -,þ. 0 0 0 0 8 ('11- ('II ('II ('II '" I\) '" -I\) 0 0 0 , . I Alaska State Plane, Zone 41 North American Datum 1927 . I\) I\) '" -0 0 0 0 0 0 8- - 400 0 400 Feet ('II - ~ - r-- , Scale: 1" = 1000' + + + , 202000 , 204000 , 206000 , 208000 ( f;y ,~ ø{J) "7 -J~~ e>'? . N'f . /~ ~ Ð, ~ I PROJECT OvERviEW EXI&TING <Õ!RAvEL ROAD 12' TO 14' WIDE >- m ! f! ~ 61 iì) J} PI if [f !PI fjf 0 I ~ i ~ JENNI50t-( TRACTS &U6DIVISIOt'-I TRACT 2 PARCEL TØIS RI4W &24 !-1M NEI/4 NWI/4 c '" ~ ~ ~ SCALE: 1" = 150' ~ ~ ~ : ~! ~~ <l~fftî ~m ~; i! ~ ~ - ~ ~ ::J ~ ~ ~ JENt-(I&ON TRACT& &UBDIVI510N TRACT 3 IDO NOT CRo&S PROPERTY LINEI~ GARRI&ON AvENUE róø' RIUJ I ~ ( JACKIN5KY TRACT B IS63 SUBDIVISION LOTI ~ æ JACKIN5K, TRACT B 1S83 ~ SUBDIVISION LOT 2 PAJ'!CEL TØIS RI4W S24 HM NI/2 SEI/4 NWI/4 f- ill ill æ f- <J> tV: ill f- J ~ Z ill :r IL ill f- <J> / ~J t ~iï\i, \:Tf !~~T ~ ~t~t ! ~å¡1 Q~"'¡¡ <!.>í!E ~ i~i~ -Ii !! !! " ! ~ .: . ~~~~- ~ ¡ \\ 9. ~ t~d~W PARCEL røls RI4UJ S24 HM SI/2 SEI/4 NWI/4 ( '" 31 ô /Jl 1:1 'JI ¡ !il if ¿'~Ð --b FARCEL TØIS RI4W S24 !-1M NI/2 SEI/4 NW1I4 I ( <- ill ~ <- <JJ æ ill <- -' ~ Z ill :r Il ill <- <JJ I I FARCEL TØl5 RI411J 524 !-1M NEI/4 NWI/4 CON5TRUCTION LIMITS EXISTING SITE CONDITIONS SCALE: I" = 100' rf LEGEND ~ -95ø----- CONT""" LINE -+ "LOF!'; DIÆCTloN ~ PAD I ""'AD I BE"'" Fe. ----- GRADE BÆAK @ WELL LOCATIoN -() I"C\IÆ!'" POL.E ~ O2 T£ST ""'-E LOCATIoN ¿J rf NOTES ~ ~...~"""""" ff Ø)~ go. ~ , § ~~ ., i! ',~. ~L..;- I"ft'.: " ".,.;- > m 2 5 ~ i ~ 0 . ~ ~ ~ ~ õ g ~ ~~ ~ ~ ~; i ; ìE ~ ~ ~ ~ ~ :3 ~ 1'> ~ ~.~ i €U! I,';- ~~¡;! II ".{~~ :!! ~ ~~~j ~ 'Ii! <;0' ~ ð t! ~§~. Q~:;l~ ~~¡!E .J ~ð"," ~ ;~~ã n ~ ~ ð ~ .' .' > ~ ~ ~ õ . 6 ~ !> ~ ~~~~~ I PROPERTY LINE ~" ", LOGGED SFORADIC TREE COvER ( lJJ'-', 31 (f jj i'l !R ¡ !II i 'S! }I / // /' .¡."'P //// / I i ,I FINISHED GRADE FAD DESIGN SCALE: I" = (fJ (f LEGEND ~ -",,--- CONTOUR LINE ... OLOPE plRECTION ~ PAD I ROAD I BE"" F6 ----- GIOAPE BRE"" @ WELL LOCATI"'" /~ -<t POWER ""LE JJ NOTES 1fJ" ~,<P ! L BASIS OF coo""INATES ARE NATIONAL "EOPETIC SURVEY MoNl!1ENT KENAI I CONTINUOUSLY OPERATING REFeRENCE OT ATI""', BASIS OF ELEVATION IS NATIONAL "EOPETIC SlIRVEY .LIOVATION FOR M""""""'T VB2, .LEVATION . '0""'" (NGYO2", 2, AREA .Nc:OMPA5ðING T"E PROFOSEP PAD ><AS BE.N L""".P. OTUMP ANP .....,.... CC.ARIN" ANP $Ur;FAC:E """BBING WILL BE ""GUIREP, .. SOILS EXPLORATION UJAS F'REJ'OI'MEP BY Me:<; ON MAY", 2ØØ1 TEOT "OLE LOCATI""'S ARE S"",,-,< ".REON. _.RENCE SOILS INFORHATION pOQJHSNT FOR T.ST ""1-. LCGS. 4, CONTCU'" REFLECT.P ~E"""'" REPRES"'" FINI"",EP "RAP. AND .XISTING "RO,JNP. 5. POzeR TRAcK BE""S TO OBTAIN APEGUATE "OMFAC:TI"'" AS P.TE",,'N.P BY outŒR'O REPRE"""TATI""'. .., C"","TRUeT T~. coNTAINMSNT 01""'. Ah INPICAT.P. FI",T WIr" AvAILABLE UJAST. """'AvATION. STOC><FILE REMAINING MATERIAL IN T"E p.SIGNAT.P B.I'M AREA 1. ,,""'OTRUeT ""OERYE PIT CONTAIN"1SNT WALLO WIT" OELE"T "ATER'AL T'r"" A, AS p.plC1.P IN P.TAIL A5. e. OE. D.TAIL AS FOR PAD "ONST"""TlDN 0""<:6, .. SEE P.TAIL Be FOR DRAINAGE BASIN SFECO. IØ. OE. P.TAIL C5 FORILELL CELLAR CONST"""TlON $ÆCS. \ \. :~SEE DETAIL B5 FOR c:ONTAINMSNT PIKE SFE"S. ~S.. D.T AILS Al. Bl. . C1 FOR AC:"." ROAP SPE<:6. 1i:,-;""~" (~~' ¡~~U 'f:;., """.0-' ~ m ~ ~ ~ ~ ~ ~ õ g 1j ~~ ~ ~ ~~ ~ ; iE ~ ~ ~ ~ ~ ~ ¡j " i3 ~ ~ ~ ~ ii~! \J' ~~.,~ I> .~,,¥ :!!.. ~)\~ ¡¡" .~~¡¡ ð~ ~§:;~ ~n~~ Q~~~ ~ ~ ~g,,~ !l!d!~ ~.f ¡¡¡ ¡¡¡ JJ . ~ . . ~ ð ~ ~ ~ 'õ ~ e i>! i>! . i ð ,.¡ " ~ ~ õ ~L~- -~ ~. .1tII UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill DRILLING PROCEDURE Prepare Site for Rig Up 1) Build Pad, dig reserve pit, and install cellar ~uild berms and ensure pit liner integrity. 2) Drill and Drive 13-3/8" conductor to refusal. Re-Ievel pad and prepare to move in rig. 3) MIRU. Install Top Drive. Surface Hole 12-1/4" 4) NU 13-5/8" Diverter. / 5) Function test diverter valve and bag p~enter. ~ up Drill pipe. 6) Spud 12-1/4" Hole and drill to 1,800' MD /1,800' TVD as a straight hole. 7) POOH With DP & RU Wireline. Run Surface hole logs. RD Schlumberger. 8) Run and set 9-5/8"~9 at + or - 1 ,800'. 9) Cement 9-5/8" with 50 x of cement. 1 0) Nipple down divert . 11) Nipple up Aand B Section Wellheads. / 12) Nipple up and test 11" BOPE, manifolds, lines and valves to 3,000 psi and 250 psi as per AOGCC 20AAC25035 regulations. ¡::'~f¡;'#<. G~tG$~ /111/ $rÝ9"¿~N/AlEU/OtL ~j) Intermediate Production Hole 8-1/2" ./' 13) RIH and test casing to 2500 psi. 14) Drill float equipment and 20' of new !9rmation, 15) Conduct FIT to at least 14.0 ppg Eq. Expect 15.5 @ Leak off. 16) Clean pits and displace hole and casing with Oil Base Mud. 17) Drill 8-1/2" Hole to 8,250' taking core at 7300'. Drill to the planned Total Depth, 8250' and 7" casing point. - Log open hole as per geological prognosis. 'p4,/ÞtHt !;p~$ A¡1js-¡>¡í~/¡;x;AJj'~£iUI1;;w~.J&.v/c.. Run and Set 7" CaSingrl,250', /" 4õ Cement 7" casing with 0 sx of cement to 3800' expectd to be 1000' above all gas shows. Displace cement with t). e. Install Packoff and change rams. Test Bop's as per AOGCC 20AAC25035 regulations. PU Clean out BHA. 7 I rJ RIH and test Casing. -t<J ' S()()Ò ~~\ ~'~'11!\.-.)~ -en:- 'lv( '(3\--0:> 18) 19) 20) 21) 22) 23) 24) Complete 25) Clean out 7" casing. 26) Clean pits and Displace with completion brine. Filter to 20 NTU's. 27) POOH. Rig up and run Cement Evaluation Tool. /" 28) PU DST tools and RIH. 29) TCP Perforate multiple zones of primary target. 30) Kill well and POOH. 31) Run Casing Scrapers to TO. POOH 32) RU Eline and Run Sump Packer. 33) Run in hole and set Isolation packer number 1, sliding sleeve, and "X" nipple. 34) Run in hole and set isolation packer number 2, sliding sleeve and "X" nipple. 35) Run 3-1/2" Prodúction Tubing with Methanol Injection lines. Set top packer. POOH POOH Pennit to drill Page 12 of47 .- UNOCAL8 South NiniJ"'-"k Pearl Welt No.1 Permit to Drill 36) / NO BOPE, NU Tree and test to 5,000 psi. Release rig. Test Well in Rigless Mode 37) Rig up and run GRlCCLIGuage Ring on Electric line. 38) Move in and Rig up Well Test Equipment. 39) Rig up slick line and shift Sliding Sleeves as necessary to test zones. 40) If a zone exists below the sump packer, run wire line guns and perforate the bottom zone. 41) Production Test as needed and either set isolation plugs or close sliding sleeves on upper zones. 47) Shut well in, Rig down test equipment, and Wait on Pipeline Tie in. Pennit to Drill page 13 of 47 . . .- UNOCAL8 UNOCAL8 1,00 - ¿ 2,00 ~oo ~oo 5,00 ,-.. - a,¡ ~ '-¡;;OO oS'" Q. a,¡ ~ 7,00 L 8,00 ~OO) 1(\00 11,00 12,00) , 0 Permit to Drill 5 South Nini~k Pearl Web No.1 Permit to Drill DAYS VERSUS DEPTH PLAN PFAIL~ 1 Imi Imnt.SJ, ~ D.ph ~ 1ùœ ~ \ 10 3) ]5 page 14 of47 '" 25 3) 35 1ùœ (lb)s) - m.JUID ŒÞRL Nd 4) 45 3) 55 00 UNOCAL8 South Nini~k Pearl Well l~O. 1 Permit to Drill PROPOSED LOCATION: WEll BORE SCHEMATIC 1570' FNL & 1970' FWL of SEC24, TIS, R14W x= 205854.039 E Y = 2224511.630 N ELEVATION: 222.5 Feet PROPOSED RKB = 16.5 ; i ; ¡ , ¡ CASING AND TUBING DETAIL SIZE WT GRAD CONN ID TOP BTM. E .. 13-3/8" 61 K-55 Butt 12.515 Surface + or- 75' 9-5/8" 47 L-80 Butt 8.681 Surface + or - 2,000' 7" 29 L-80 Butt 6.184 Surface + or - 8,250' Tubing 3-1/2" <t.ø L-80 Butt SC 2.441 Surface +or-9500' 3/8" .25 416 SS Continuous .25 Surface 2500' 1 - - .. : - JEWELRY DETAIL NO. Depth ID OD Item 1 16.5' Tubing Hanger, 3-1/2" 2 TBO 4 7",29#, FH Packer 3 TBO 4 "X" NIPPLE 4 TBO 2.812 SLIDING SLEEy..cMO 5 TBO 2.812 SC-I PACKER 6 TBO "X"NIPPLE 7 TBO SLIDING SLEEVE CMO 8 TBO .25 .375 MODEL "D" SUMP PACKER "",,' 9 TBO "X" NIPPLE 2 ~~ ,~ 3 5 ~~ -- , ; " ¡ j A ZONE 7 Date AroNE BroNE CroNE Zone TEST TEST TEST PERFORATION HISTORY Interval ~ Btm h ~~ TBD TBD TBD TBD TBD Amt #VALUE! #VALUE! #V ALUE! Accum. spf Comments 6 :g],~ ~¡ '-- 8 9§ C ZONE - PBTD AT FLOAT COLLAR TD = 8,250' Pennit to Drill page 15 of 47 UNOCAL8 South Ninil~ Pearl WeI11~o. 1 Permit to Drill STRATIGRAPHIC TOPS OF FORMATIONS Union Oil Company of California Proposed PEARL. #1 Well Geologic Tops and Correlations Marker Base Glacial Top Sterling Beluga Tyonek Tyonek Target TOTAL DEPTH Pennit to Drill Correlation Well Proposed Well Mobil Ninilchik Unit #1 PEARL# 1 MD TVDSS MD 220 +15 220 220 +15 220 1362 -1124 1362 4060 -3822 4060 6800 -6563 6800 8250 -8013 8250 page 16 of 47 TVD 220 220 1362 4060 6800 8250 Elev RKB 221 237 TVDSS Difference +15 0 +15 0 -1124 0 -3822 0 -6563 0 -8013 0 .. UNOCAL8 South Ninil("""""{ . Pearl Welll~o. 1 Permit to Drill SOUTH NINILCHIK PROPSPECT PROPOSED PEARL Well No.1 Hazard Analysis for APD 20AAC 25.005 (c) 4 (A) Maximum pore pressure anticipated is 3,710 psi at 8,250' TVD based on 8.65 ppg EMW. Offset wells were drilled with mud weights ranging from 9.5 to 11.6 ppg. The three closest offset wells are the Brinkerhoff Ninilchik River # 1, The Mobil Socony Ninilchik Unit # 1, and the Union NINILCHIK # 1. The Mobil Socony well is adjacent to the location and is the type log. The Union well is now known as the Susan Dionne well, currently being worked on by Marathon. The higher than normal mud weights used during the drilling of these old wells was likely a result of insufficient mud cleaning equipment as the muds were repeatedly watered back). (B) No Losses were recorded in the drilling of the offset well. In the event of lost circulation, adequate supplies of lost circulation material and water will be kept on location. Crews will be briefed on the strategy for dealing with losses should they occur. (C) H2S production has not been identified in any of the Offset well information files available to Unocal. (D) Cuttings and Mud will be temporarily stored on location until an injection well can be permitted and the cuttings disposed of via Grinding and Injection into a Class II disposal well. The pit will be constructed to store Oil Base mud cuttings in one pit and water base mud cuttings in a second section of the pit. (E) Coal seams have a history.of causing sticky hole and cavings. Short (5 foot) sections of the coals shold be drilled to determine if the hole will cause sloughing. Picking up out of the coal seam and observing the weight indicator to check for drag will be standard prevention and detection practice. (F) Proximity to the offset well is an issue during the Top hole portion of the well. The offset Mobil Socony well is some 200' away from the proposed well. Deviation will be controlled such that the offset wellbore is always greater than 100 feet away from the wellbore. Permit to Drill page 17 of 47 ,-... , ..!ft8 UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill South Ninilchik Prospect Pearl Well No.1 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the South Ninilchik Pearl # 1. The pore pressure gradient was estimated from the following information: BHP Depth Well Q§i TVD EMW. PPg Comment . DCU # 1 4441 10254 8.65 * Open Hole DST with no flow. 6" ,,<,les. ¡":->6. A/J * Chlorides on fluid entry were 70 GIG. Limited fluid entry. Sand pressures are estimated to be less than seawater gradient. Results from the NNA # 1 well currently being drilled will also be considered and used to predict needed mud weights. Union Ninilchik #1 (NOW SUSAN DIONNE # 1) was drill stem tested and several completion 3 l1.uk-:- lo/\¡&- attempts were made at the 3770' interval. Flow indicated some gas and water and that the BHP at this depth was less than 9.0 ppg. The completion attempts included a squeeze, reperforate and retest. The well has changed hands several times and has not produced commercial quantities of gas from this depth. Marathon is now the owner of this well and will be attempting to complete deeper. The well has been renamed the Susan Dionne. The fracture gradient for the surface and intermediate casing points was conservatively estimated at .806 psi/ft or 15.5 ppg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling ü.oJ (TVD ft) (lbs/Qal) (lbs/Qal) (lb/gal) (Q§j) (Q§j) 9-5/8" 1,800' 15.5 8.65 9.2 809 1,364 7" 8,250' 15.5 8.65 9.5 3,710 2,885 Procedure for CalculatinQ Anticipated Surface Pressures While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat plus 1 ppg safety factor with casing evacuated with gas. or 2) formation pore pressure at the next casing point less methane gradient to surface as follows: 8-1/2" Production Hole Section from 1,800' TVD to 8,250' TVD 1) ASP == ((FG+1 )x.O52xD) - (MWx.O52xD) = (16.5x.052x1800) - (O.10x.1800) = 1,364 psi Pennit to drill Page 18 of 47 ~ UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill OR 2) ASP = PPx..052xTVD'- (0.1gas gradient xTVD) = 8.65 x.052x8250 - (0. 1 Ox8250) = 3,710 - 825 = 2,885 psi 19 01/05/02 South Ninilchik PEARL No.1 ~ ..- UNOCAL8 ~ South Ninilchik Pearl Well No.1 Permit to Drill LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drill pipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. A non-permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure-vs-cumulative volume pumped, Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak-off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak-off pressure is calculated as follows: Leak-off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded under any circumstances. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. TYPICAL PIT PLOT [psi) C "--~ SURFACE PRESS. VOLUME PUMPED [BBLS) SHUT -IN-TIME [hUN) NOTES: Point" A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. 20 01/05/02 South Ninilchik PEARL No.1 "'--"'" .~. UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill DIVERTER AND BOP SPECS Diverter The diverter will consist of a 13-5/8", 5,OOOpsi Annular Preventer and a 12" O.D. non bifurcated vent line. The vent line will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The Vent Line will be a minimum of 100' away from any source of ignition. Blow Out Preventers The blowout preventor will consist of a 11", 5000psi Annular, a 11", 5,000 psi double ram preventor with pipe rams on top and blind rams on bottom, a 11", 5000 psi mud cross w/ 3-1/8",5000 psi flanged outlets, and a 11", 5000 psi single ram preventor with pipe rams. Choke Manifold The choke manifold will be a 3-1/8", 5000 psi manifold. It will include 1 ea. remote controlled hydraulically actuated choke and one hand adjustable choke. Casing Test MASP Test BOPS Low/High Casing String Size (in) (psi) (psi) Size and Rating (psi) Conductor 13-3/8" N/A N/A 13-5/8" 5M Annular Function Surface 9-5/8" 1629 2000 11", 5M Annular 250/3000 11", 5M Pipe Ram 250/3000 / 11",5MPipeRam 250/3000 11", 5M Blind Ram 250/3000 Production 7" 4017 250011", 5MAnnuiar 250/3000 11", 5M Pipe Ram 250/3000 ./ 11", 5M Pipe Ram 250/3000 11", 5M Blind Ram 250/3000 Wellhead Manufacturer Model Cameron MB Split Multibowl System, 11" 5M Starting Head SOW, 13-3/8" x 13-5/8", 3M w/ XXX Outlets preped for Mandrel Hanç¡er Casinç¡ Head 13-5/8", 3M x 11", 5M, w/9-5/8" Csç¡ Mandrel Hanç¡er and Pack Off Tubing Spool 11", 5M x 11" 5M Tubing Hanger 11", 5M w/3-1/2" EUE 8rd Lift x 3-1/2" Imp Mod Butt Suspension w/Type H BPV Prep 21 01/05/02 South Nini1chik PEARL No.1 ~. .~. UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill CASING DESIGN Suñace Casing: 9-5/8", 47 #, L-80, Buttress Worst case for burst would be in the event of a gas kick while drilling at TO (8,250'). If the Maximum Anticipated Surface pressure were encountered, the SI pressure against the 9-5/8" surface casing would be 1250 psi. This is based on a 15.5 ppg fracture gradient plus 1 ppg safety factor with the casing full of gas. Burst = 1364 psi. 9-5/8",47#, L-80 rated @ 6,870 psi for burst Safety Factor = 6870/1364 = 5.03 OK Worst case for collapse is if returns are lost while drilling below the 9-5/8" Surface Shoe Collapse = (10 x.052x 1,800') = 936 psi for full evacuation 47#, L-80 rated @ 4,760 psi collapse Safety Factor = 4760/936=5.08 OK Worst case for tension is if the shoe of the pipe were packed off and the resultant end area buoyancy did not apply. This is equivalent to using air weight. A 100,000 pound overpull is also assumed in the calculation. Tension = 1800' X 47# = 84.600 K Max pull = 84.6+100 = 184.6 K Rated = 1 086K for body yield Safety Factor = 1086/184.6=5.88 OK Production Casing: 7", 29#, L-80, Buttress Worst case for burst would be in the event of a gas kick while completing at TO (8250'). If the Maximum Anticipated Surface pressure were encountered, the SI pressure against the 7" production casing would be 2,885 psi. Burst load = 2,885 psi. 7",29#, L-80 is rated @ 8160 psi for burst Safety Factor = 8160/2885 = 2.82 OK Worst case for collapse is if plugged perforations occur while flowing the well with the tubing empty below a packer. Collapse = (10 x.052x8250') 29#, L-80 rated @ 7,020 psi collapse = 4,290 psi for full evacuation Safety Factor = 7020/4290=1.63 OK Tension = 8,250'X29#+1 OOK = 239.25 K Rated = 597K for body yield Safety Factor = 597/339.25=1.75 OK 22 01/05/02 South Ninilchik PEARL No.1 ,,-...., IF UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill CASING PROGRAM SUMMARY Deep Creek Prospect PEARL Well No. tasing Program Casing API Values Casing Casing Hole Size Set From Set to Weight Casing Conn Size Burst Collapse Tension (in) (MD) (MD) (ppf) Grade Type (in) (psi) (psi) (K Ibs) 9-5/8" 0 1800 47 L-80 Butt 12.25" 6870 4750 1086 7" 0 8250 29 L-80 Butt 8.5" 8160 7020 597 Casing Design Frac Formation Design Factors Casing Casing Setting Gradient Pressure Size Weight Casing Depth at shoe at shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9-5/8" 47 L-80 1800 15.5 967 1364 5.03 5.07 5.88 7" 29 L-80 8250 15.5 4376 2885 2.82 1.63 1.76 Casing Design Discussion Maximum loads are used to calculate the safety factors. In the case of burst, the hole is evacuated with gas. In the case of Collapse, the inside of the casing is assumed completely empty. The tension safety factors are based on air weights of each string with an added 100,000 # overpull. 23 01/05/02 South Ninilchik PEARL No.1 UNOCAL8 ~ South Ninilchik Pearl Well No.1 Permit to Drill CEMENT VOLUME CALCULATIONS .,.~I!. .4F~'" ..~.ilL."... UNOCAL8 Surface Casing Size: 9.625 Setting Depth: WI. 47 Annular Vol to ID: 8.681 Shoe Track Vol Desired Volumes including excess Desired Top of Lead Cement Desired Length of Tail Cement Lead Slurry: Top of Cement: Bot of Lead Cement Specifications: South Ninilchik Prospect PEARL Well No.1 Cementing Program 1,800 MDI 1800 TVD 909,3781 Cubic Feet 1,800 with 12.25 gauge hole: ~ ft3 563.6641 1473.042 Cubic Feet 80 32.87759 Cubic Feet 30% % EXCESS Vol Req'd 766 ft3 0 feet 500 feo/ì / ppg, Yield: W Sx: 281 CF: ~ft3 529.218 0 VD 1,300 I 202 CF: 236 ft3 236.423 Check 765.6409 Density: 13 0 MD 1,300 MD Class G with Additives Mixed with Fresh Water ~ Density: 15.8 ppg, Yield: ((;7 ) Sx: 1300 MD 1300 ~ Class G with Additives Mixed with Fresh Water Tail Slurry: Top of Cement: Specifications: Production Casing Setting Depth: OH Annular Vol to Cased Hole Ann Vol to ID: 6.184 Shoe Track Vol Desired Volumes including excess Desired Top of Lead Cement Previous Casing Shoe Depth Desired Length of Tail Cement Lead Slurry: Density: 13 Top of Cement: 3800 MD Bot of Lead Cement 5,000 MD Specifications: Class G with Additives Mixed with Fresh Water Size: WI. 7.000 29 8,250 8,250 Na 120 30% % EXCESS 3800 feet 1800 feet/, 3250 ~ei / ppg, Yield:. 1.88 3800 \fV 5,000 D MDI with MDI Tail Slurry: Top of Cement: Specifications: ~/-\ (II Density: 15.8 ppg, Yield:!....1:..!Z.! Sx: 5000 MD 5000 ~ Class G with Additives Mixed with Fresh Water 24 01/06/02 8250 TVD 8.5 gauge hole: --111 ft3 na Guage hole: ft3 25 561 412.0755 412.0755 25.02596 Vol Req'd ( Sx: 91.8 CF: ~ft3 172.5016 / 479 CF: ~ft3 560,7241 Check 733.2258 South Nini1chik PEARL No.1 25 .- UNOCAL8 13-5/8", 5M x 13-5/8, 5M 70.75" . ~ South Ninilchik Pearl Well No.1 Permit to Drill DIVERTER STACK UP DRAWING Fill Line 13-5/8", 5K, Shaffer Annular G ) I -I - I 60" . t ~I 53.75" I Need new spool . . ~ I \ 17" '" , 0 1/05/02 I (' T ~ ---- ---- Flow Line I " I I I ~ j 12", Hydraulic Operated 1/-"'- \ 1_1..- - 12" , Diverter Line H = 2.5'(Ô) CL I 36" + 1 13-5/8", 5M x 13-5/8, 3M Crossover e"""" I 13-5/8" 3M f Starting Head 8.5' Welded I . ---- 13-3/8" UNOCAL81 Diverter Hookup Well NNA No.1 East Side Kenai Peninsula Drawn by: J.I.M. Date: 10-21-01 South Ninilchik PEARL No.1 .- UNOCAL8 ,~ South Ninilchik Pearl Well No.1 Permit to Drill BOP STACK DRAWING ----- ----- t 11", 5M, Shaffer Annular 41-1/2" --- ---- I I .. I I .. . , 11", 5M, Shaffer Double Gate ~II I " " I II~ 33" ~II I II II I II~ I I .. t 11", 5M, Mud Cross D= =iJ 24" I, I .. .. 11", 5M, Shaffer Single Gate ~II I II II I II~ 19-1/2" ~ I I 11", 5M, Spacer Spool t t 24" ... ~ 12" f \\"5M x \\"5M 15.75" Cameron + ,----, MB Tubing ~ I Spool 70.75" + ~m - J1f=D \\"5M 26" x 13-5/8" 3M ¡ Cameron I I MB Spool 11 I 13-5/8" 3M 17" ¡ f Starting Head . " + 8.5' " I ~~~J 7" . ---- 13-3/8" Welded 9-5/8" UNOCALel BOP Hookup Rev I Well NNA No- 1 East Side Kenai Penninsula Drawn by: J.I.M. Date: Revised 10-21-01 26 01/05/02 South Ninilchik PEARL No.1 , , ! ,-. /'"'""'" TO FlARE TO FLARE TO DEGASSER . .......... i ~ I: : I~. :OIOI: ] ~ :t" :r" Å .~ PLAN VIEW CHOKE UNE FROM B.O.P. Ie!) e el II . ~ . ~ . ~ . ~ . SECTION' AA ' DRlWNG INC. Rig 9 Choke Manifold 3" x 5,000# . .~....¡'~.. ' MUD 2/1:~ . .. I' .. S' ~ tHF- ~J . ". -~ , .... - . . .: =: ~.,. -~ -+ -~ ' .'~ A ~ ~ r .. ~~.. .. ) s' .. Q .. X .. X . Q ... .. Q I ~r 160 bbl I .~s' 0 IIUD IIIX HOPPER I' I 40bbl ..... C . /~. I I PILL TANK .. LEGE.ND -0-- CONCalTRIC RF!1UCER - GATEVN..VE X AGITAlOR --IN!- BUTTERf1.Y V#J.VE C/W FLANGES -Q- SUCTION VALVE. lEE 1YPE ~ SUCTION V#J.VE. ELL 1YPE , .. )( ... r Q r Q r ~/ f" 160 bbl I I .. I cg I!OTTOII MUD GUN LOW PRESSURE TYPE ~ANI(ECUAI.IZER ,J ~ SKlIIIIER P e" FlOW UNE TO MUD PUMPS . Tþ~ r g r Q ~ / I 160 bbl I .. WELL R£IURNS I .. -~t~ .. I .. ') J I -- Ì)Í....- I I ~ J :' s' r;\' .ili~~~ -; ~ . QrX. 2=--,)( ~. ...~oO 1°. ~ L I ~"- I J. "0 ~ ~" I 190 bbl -, I 185 bbl I- MAN: - ~ ." 1...-- 1 CENTRIf\JGE ] ~ - TO SUIIP '----' T~w x ... ~3" MUD SYSTEM SCHEMATIC - NOT SHOWN ARE TANK CI.£AN-oUTS SUMP SUCTIOH OR STE:AII tRACE UNfS Total Active System = 1.135 bble (Not Including Trip Tank) , .. \ A\ \ I I 40bbl TRIP TANK )- I 240 bbl .. r~ 36" MUD GAS SEPARATOR . '10 FLARE .J .. . .1 -- 1..1-1- .. . .a. IIIIIWIIG JRC, -- RIG I I @)-E3- "'-.".. MUD TANK SCHEMA11C i- ~ , ~ . ¡ , \ ¡ ¡ i I ~ ~ j , i i I I I L . ~ " t I-]-~~ þ~! -- <Ð '- ÌE .! _: :_,(~ !, I . l:~ ~ .' -', -<: L: - J¡, 0 '" -""^- mIl 1:1 II ~ <:L' ~ ~ f!I ~ ~~ '9'7-! Ø\[ )\00) I~L --, 'Y,~'- ~1~:I~::11 ~.11 5 1 ¡; ~ l ! L ~ ~ 'I ~ ~ .-., ., ~ U- ~¡ ~ - .. I:,>, .~ 0 ù W ~L : ~~i:U ~ il ~ ., I; ~i-- ;¡ i - ~u= g- : i~¡¡ lS¡ ~c old 1::1 - . It l¡}iJ~ -¡ - ~ ~ ~ ..ry-- I f ~ f ~ ~ 1 c .. --.>0- ~ ~ ~ ~ ~:l\ V - - , ~~- - ~ ~þ s::::tt' ~ ~ ~ s.::ñ-' . ==- ==- ~ -=- ~ ~ ~II - -S-~-S--S-~-S;-~ ~. ~:§:~~~;Z ~'i - - ~ ~ ..:::=-- ~ ~ '~11 . I , j I j ¡ J i , ;. èj ~1 ~! " '~ .r::rr ," ;J ;~ i; "." ..", :"'; ù }~ ") ;;,1 l1 ~ -. . d ~D ~. -- "---- .. ,~ 5 d W 0 - i$~~D~ ~L -! ù hl% $ . .. . ~~...: -" ~" - ~7~H i~ LI D;åiH i5õ I .:os 3"" z.. tzI ~riI ¡{- It i I;l~, " II. JL ~ ... .. IJ 'I IDDLJLJn--,O r It Inl M' 1\ IU~ I[ D[ ~ ",I --"- ~ UNOCAL8 South Ninilcnik Pearl Well No.1 Permit to Drill MUD PROGRAM Interval Summary 0.1800' MD 95/8" Casing 12 1/4" Hole Drilling Fluid System Gel- Gelex Key Products M-I Gel / M-I Bar / Soda Ash / Caustic Soda / Gelex / DD / Sapp / Drill XT Solids Control Flow Line Cleaners / Centrifuge / Desander / Potential Problems Hole Cleaning / Gravel/Gas Kick / Lost Circulation / Bit . Interval Drilling Fluid Properties Depth Mud Plastic Yield Gel API Total Interval Weight Viscosity Point Strength Fluid Loss DrilledSol- ids (ft) (ppg) (cp.) (lb./10Ott2) (lb./100tt") (ml/30min) (%) 200 8.7 5-10 20 - 30 N/C < 20 3 or less 1500 9.2 / 7-12 15 - 25 12 12 -15 5 or less 1800 9.2-10.0 10-15 10 - 20 10 - 12 < 10 5 or less . Build spud system with pre-hydrated bentonite and Gelex in fresh water. . Utilize all solids control . Raise viscosity if gravel sections are encountered. . Pump sweeps if required. . Add DD (drilling detergent) and/or Sapp for possible bit . Potential Problems: Running gravel, bit balling, shallow gas, and swelling . Lower fluid loss to below 10 cc's API by end ofnterval with Polypac additions. . Estimated volume usage- 1200 balTels. Note: Mud Weights of 10.0 ppg may be required because fpotential shallow gas. 31 01/07/02 South Ninilchik PEARL No.1 UNOCAL8 ~ South Ninilcnik Pearl Well No.1 Permit to Drill Interval Summary 1800' - 8250' Drilling Fluid System Versa- Drill Oil Mud Key Products Mapco 200 / Versawet / Versacoat / Versa HRP / -69/ Ver- samod / Lime / Calcium Chloride / MI Bar / Ventrol Solids Control Shale Shakers / Desilter / Potential Problems Coal sloughing, hole cleaning, drill solids Interval Drilling Fluid Properties Depth Interval (ft) 1800' -8250 Mud Plastic Yield HTHP Weight Viscosity Point Fluid Loss (ppg) / (cp.) (lb/100ft2) (ml/30min) 9.5-10.5 20-25 12-20 4-5cc's OIW Ratio 80/20 Gels (lb/100ft2) 15- 30 . Build 30- 40 barrel spacer to pump between spud mud and oil based mud. . Displace hole to oil based mud. Insure spacer and I based mud are properly discharged. . Drill ahead, maintain low shear rate values with -69, Versamod, and Versa HRP. . Run centrifuge as needed to reduce solids buildup. . Pump weighted sweeps to aid in hole . If sloughing coal becomes a problem, adl2- 4 ppb ofVentrol401 to mud system or spot a concentrated pill of20- 25 ppb Ventrol401 across coal zone prior to For severe coal sloughing consider raising mud . Run 7" liner. . Displace well to brine after running tubing. Pump a leenup spacer for displacement to 6% KCL. . Estimated volume usage is 1600 barrels. 32 01/07/02 South Ninilchik PEARL No.1 ~ UNOCAL8 South Ninilcnik Pearl Well No.1 Permit to Drill Interval Summary 1800' - 8250' Lost Circulation Recommended LCM Pill Formulas Problems Key Products Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / HRP Lost Circulation Pill (Slight Losses) Volume Mix II SafeCarb SafeCarb Versa HRP of Mud Fine Medium (barrels) (ppb) (ppb) (ppb) (ppb) 30 10 10 10 1/4 . Lost Circulation Pill (Moderate Losses) Volume Mix II SafeCarb SafeCarb Versa HRP of Mud Medium Coarse (barrels) (ppb) (ppb) (ppb) (ppb) 40 15 15 10 1/2 Lost Circulation Pill (Severe Losses) Volume Mix II SafeCarb SafeCarb Versa HRP of Mud Medium Coarse Polymer (barrels) (ppb) (ppb) (ppb) (ppb) 50 15 20 30 1 . Versa HRP should be added last, only after all lost circulation material has been . If possible, spot pill across theft zore. Apply moderate pressure (50- 100 psi) to squeeze pill into thief zone. 33 01/07/02 South Ninilchik PEARL No.1 ~ ~ ~-- UNOCAL8 South Niniicbik Pearl Well No.1 Permit to Drill Well Summary Casing Size Hole Size Casing Program 95/8" 12 1/4" 7" 8 1/2" Key Issue No.1 Cuttings DÙ.,posal Key Issue No.2 Drill Solids Build-up Key Issue 3 Hole Stability Slough- ing Coal 34 Depth Sum Days Cumulative Mud Cost lVD Mud System Mud Weight 1800' 1800' GellGelex $18125 8.8-19» 5 8250' 8250' OBM 10.0-10.5 ,// 10 $166250 . Cuttings Disposal will be an issue. Mud and cuttings should meet all disposal requirements and limitations. OBM t- tings will require special . Run as fine a mesh screens on shakers and centrifuge if 1- able to reduce the build up of drill solids in the mud. u- fion and/or chemical additions may be needed to reduce pro- gressive gel strengths. . Maintain mud weights as per program. Increase rheology as required by hole conditions. 01/07/02 South Nini1chik PEARL No.1 ~ ,-.- UNOCAL8 ~ South Ninilchik Pearl Well No.1 Permit to Drill SALINITY CALCULATIONS South Ninilchik Prospect Area Salinity Calculations from Well Logs Offset Well: Mobil Ninilchik Unit #1 Well Location: Sec. 24-T1S-R14W Date Drilled: 1964 Mobil Ninilchik Unit #1 SP METHOD Depth Tgrad Tf SP Kc Rmf @Tf Rmfeq Rweq Salinity Porosity (ft) (F/ft) (F) (mv) (ohmm) (ohmm) (ohmm) (ppm) 185 0.0085 67 7 69.9 5.7 4.9 3.85 1500 0.3 441 0.0085 69 16 70.1 5.5 4.7 2.79 2000 0.3 620 0.0085 70 22 70.3 5.4 4.6 2.25 2700 0.28 910 0.0085 73 25 70.7 5.3 4.5 1.98 2800 0.3 1150 0.0085 75 35 70.9 5.1 4.4 1.40 4000 0.29 1930 0.0085 81 35 71.8 4.7 4.0 1.31 4000 0.25 2265 0.0085 84 23 72.2 3.1 2.6 1.26 3800 0.22 3435 0.0085 94 21 73.5 2.8 2.4 1.22 3700 0.2 4370 0.0085 102 20 74.6 2.6 2.2 1.18 3500 0.24 5920 0.0085 115 30 76.3 2.3 2.0 0.79 4500 0.22 7840 0.0085 132 45 78.5 2.0 1.7 0.46 7000 0.19 9080 0.0085 142 23 79.9 1.3 1.1 0.58 5000 0.17 10600 0.0085 155 45 81.6 1.2 1.0 0.29 9000 0.14 Notes: Tsurf = 65 F BHT = 164 F @ 11640' Rmf = 6.0 @ 63 F Run 1 to 2013' Rmf = 3.8 @ 67F Run 2,2013' to 8757' Rwa METHOD Rt F Rwa Salinity (ohmm) (ohmm) (ppm) 60 8.3 7.27 800 25 8.3 3.03 1900 23 9.6 2.40 2450 12 8.3 1.45 3800 11 8.9 1.24 4700 21 12.2 1.72 3000 - 25 16.1 1.56 3100 25 19.7 1.27 3400 16 13.3 1.20 3500 12 16.1 0.75 5100 10 22.0 0.45 7100 12 28.0 0.43 6900 10 42.5 0.24 11500 I' I~úð N'þ ~~- italics = estimated values; porosity logs not run above 1977 ft Salinity from Schlumberger Chart - Resistivity of NaCL Solutions Base of freshwater indicated on Dual Induction 109 at 205' MD 35 01/07/02 South Ninilchik PEARL No.1 ~ UNOCAL8 South Ninñcnik Pearl Well No.1 Permit to Drill SHALLOW GAS HAZARDS AND SEISMIC VELOCITY ANALYSIS Unocal Alaska Unocal Corporation 909 West 9th Ave. Anchorage, AK 9950 I Tele: (907) 263-7664 Fax: (907) 263-7828 E-mail: SMITHL@unocal.com UNOCAL8 Larry J. Smith Sr. Advising Geophysicist January 4,2002 AOGCC 333 w. 7th Ave., Suite 100 Anchorage, AK 99501-3539 Attn: Steve Davi~S Dear Steve: Re: Pearl-l Permit to Drill- Shallow Gas Hazards and Seismic Velocity Analysis Please find attached 8 figures I produced using Unocal's new seismic line that passes through the proposed Pearl location. Figure 1 shows the top Tyonek structure map for the South Ninilchik unit that predates the addition of the new sesimic line. The location of the new line, UNTZO 1-1 0, is shown on the map. I am currently in the process of updating the maps to reflect the rollover to the north of the proposed location into the cross faults as seen in Figure 3. Also posted on the map are the three offset wells that are shown in Figure 2. In Figure 2 you can see that the two closest wells to the Pearl-l location, BrinkerhoffNinilchik River-l and Mobil Ninilchik U-l, were both spud in with 10 to 10.25 Ibslgallon mud indicating no shallow gas problems. Also no intervals in these wells were weighted up in excess of 10.25 Ibslgallon indicates that there were no overpressured intervals encountered. Figure 3 is the interpreted seismic line showing the major fonnation tops as well as the location ofthe Mobil Ninilchik U-l and the proposed Pearl-l locations. The expected pay intervals lay between the Top Tyonek and the lower of the two green markers within the Tyonek. As you can see, the Pearl-l location is practically a twin to the Mobil well with only being offset by approximately 200 feet to the north. As you can also see in Figure 3 there appears to be no shallow bright spots visible on the seismic line at the Pearl location. The isovelocity plot ofline UNTZOl-10 is shown in Figure 4. The Pearl and Mobil locations are posted on this display at the appropriate CDP locations. The velocity analysis at CDP 615 is the closest to the proposed Pearl location. The other labeled CDP's are the velocity points used in the seismic processing. As you can see no major lateral changes in RMS velocity are apparent in this display. Figure 5 is the depth verses RMS Velocity (or average velocity) for the five closest 36 01/07/02 South Ninilchik PEARL No.1 -.- UNOCAL8 r'-\ South Ninilchik Pearl Well No.1 Permit to Drill CDP's to the Pearl location. As you can see in the plot, all functions track each other very closly in the shallow section from 0 to 5000' depths. In Figure 6 the depth verses Interval velocity for the same five CDP points are plotted for the total depth ofthe seismic section. In Figure 7 the same data is plotted again but only for the interval of 0 to 12,000 feet. At this scale you can see that the velocities for all CDP's except 565 are direct overlays to each other. The fact that CDP 565 shows faster shallow interval velocities indicates that there is a decreased risk of shallow gas to the north of the proposed location (since this would lower the velocities). Below 3000' the interval velocities diverge with the spread ranging from 9000' /sec to l2,000'/sec. CDP 515 has the highest interval velocity but I suspect that this is an artifact of the shot skip between shot points 275 to 285 (CDP 550-570) which reduces the fold of the shallowest section making the velocity picking more dubeous. Figure 8 is a tabulation of the velocity data for the CDP's plotted in Figures 5, 6 and 7. So in summary, based on the lack of shallow gas in the Mobil Ninilchik D-l offset well and the lack of any shallow bright spots on the seismic line, I don't believe that there any concerns regarding shallow gas at the proposed location. Also since the Mobil well encountered no over pressured intervals deeper in the section, I don't think we will encounter any over pressured intervals at the Pearl location either. Please look at the data and let me know if you have any questions or concerns. Sincerely, Larry J. Smith 37 01/07/02 South Ninilchik PEARL No.1 - UNOCAL8 ,~ South Ninilcnik Pearl Well No.1 Permit to Drill 8 ~- N N ~ -~ 195000 210000 217p<JO ~.. 1- - ~, y ~ ~ N -..... S 0 . 8 ~- ~ 28 27 Unocal Proposed Pearl-1 With Top Tyonek Structure Map and Seismic Line Used in Velocity Study +~~ \... .~~ "'-~ . 8 ( "", ----- , I '1'10.1 ~/'n.--"'- 217500 225000 " 195000 202500 210000 38 01/07/02 South Nini1chik PEARL No.1 - UNOCAL8 ~ South Ninilcnik Pearl Well No.1 Permit to Drill UNOCAL8 PEARL Offset Mud Weights 0 2000 ------- . ~ 4000 . '> . 6000 . ê ~ .c 8000 ë. Q c . . ~ . . . -- . 10000 . . . 12000 ~ SOCONY MOBIL UNIT NINILCHIK 1 ~ UNION NINILCHIK 1 MUD 14000 - BRINKERHOFF NINILCHIK RNER # 1 16000 9 9.5 10 10.5 11 11 .5 12 12.5 13 Mud Weight (PPG) 01/07/02 South Nini1chik PEARL No.1 39 ,...¡ .= 0 .- .::ai: '7 ¡.. .... ~".... -=-0111( ~ ~ 0 = ~- .... - z .- -= 1: Ë -= ~ ~ 0 ~ ~ r:n~ ~. .... 'C U 10 'z :::1 ~ ~ 00 '<t 4-< 0 ...... '<t ~ 0 ..... 'ê 0 p... UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill rïi I Cont rol paramete rs " . U;.J .,....., l ~ ¡ t.IIJL~ [8¡0'1 Ii""" J l1 ~" Display S(~n(t PROJECT: UNO2DTZ LINE: UNO1.0 1.65 21.5 265 31.5 0- IDENT: DVEL RMS VELOCITY 665 71.5 765 81.5 CDP 465 51.5 565 61.5 365 41.5 ¡ ! 4000-12 I . I 4500- ; i 5000 1~O i : - I 5499 f:..J 9699 6999 $299 7::'99 6 :'3 99 6199 I~ 01/07/02 42 of 47 South Ninilchik PEARL No.1 ) ) UNOCALe South Ninilchik Pearl Well No.1 Permit to Drill Depth VS Average Velocity For Line UNTZO1-10 14000 13000 12000 11000 10000 i È 9000 r 8000 7000 5000 4000 0 5000 10000 01/07/02 43 of 47 15000 20000 Depth (ft) South Ninilchik PEARL No.1 25000 30000 II! 35000 ') / -COP515 - COP 565 COP 615 --- COP 665 - COP 715 ) UN 0 CAL4' Depth Vs Inte~~~ittilt.bikuNTZO1-1 0 .., Pearl Well No.1 -T--~~.. ..--......-..T.... ... ... .PernittoDri 20000 18000 16000 14000 12000 i III £ 10000 ... .5 > 8000 6000 4000 2000 01/07/02 I I III T I I III J- III ~II I ~V-- I I' 0 a 5000 10000 44 of47 15000 20000 Depth (ft) 25000 30000 South Ninilchik PEARL No.1 35000 ) -- COP 515 -- COP 565 COP 615 ~ COP 665 --COP 715 ) UNOCALe 18000 16000 14000 .-. 12000 ! 1: :> 10000 8000 6000 4000 0 01/07/02 South Ninilchik Pearl Well No.1 Permit to Drill Depth VS Interval Velocity- Line UNTZO1-1O 2000 4000 45 of 47 6000 8000 Depth (ft) South Ninilchik PEARL No.1 10000 12000 14000 ) ~ CDP 515 - COP 565 COP 615 -7'- COP 665 ~ COP 715 ) UNOCALe Pean-1 Offset Velocity Study- Line UN1Z01-10 CDP 515 TWT (ms) Vrms Depth 0 5499 266 6718 534 7347 800 8050 1000 8789 1218 9344 1478 9787 1752 10046 2088 10749 2588 11414 3018 11784 3410 11936 4132 12375 4998 13012 CDP 665 TWT (ms) Vrms Depth 0 6000 140 6497 408 6940 658 7384 882 7976 1178 8271 1418 8530 1676 8715 1908 8752 2152 9344 2512 10231 2886 10823 3250 11599 3730 12112 4384 12612 4998 13012 01107/02 Vint 0 893 1962 3220 4395 5690 7233 8800 11222 14770 17782 20351 25567 32517 Vint 0 455 1416 2429 3517 4872 6048 7303 8349 10054 12850 15618 18848 22589 27646 32517 6718 7971 9461 11745 11890 11862 11443 14415 14191 14011 13106 14448 16051 6497 7171 8109 9715 9150 9801 9732 9019 13973 15533 14799 17752 15585 15464 15868 46 of 47 South Ninilchik Pearl Well No.1 Permit to Drill CDP 565\ TWT (ms) Vrms Depth 0 6000 180 6440 380 7273 624 7865 818 8197 1002 8604 1262 9085 1560 9159 1900 9492 2240 10379 2688 11083 3044 11554 3516 12053 4202 12597 4998 13012 ¡CDP 715. lWT (ms) Vrms Depth 0 6000 144 6497 376 7088 592 7458 794 8123 1074 8604 1314 8937 1560 9196 1888 8974 2148 9122 2382 9676 2696 9935 3044 10342 3532 11340 3942 12043 4446 12612 4998 13012 Vint 0 580 1382 2454 3353 4311 5733 7144 9017 11624 14896 17585 21189 26466 32517 Vint 0 468 1333 2208 3225 4620 5872 7173 8471 9797 11524 13392 15741 20026 23737 28036 32517 6440 8023 8787 9265 10413 10939 9472 11020 15336 14603 15110 15271 15385 15203 6497 7455 8102 10072 9968 10427 10579 7918 10197 14761 11900 13495 17565 18099 17062 16234 South Nínilchik PEARL No.1 CDP 615 1WT (ms) Vrms Depth 0 6000 274 6352 518 6940 770 7645 984 8050 1194 8382 1430 8678 1672 9307 1956 9639 2304 9996 2718 10584 3170 11340 3624 12053 4028 12553 4522 12905 4998 13012 Vint 0 870 1797 2943 3961 5004 6205 7781 9427 11515 14384 17974 21840 25282 29178 32517 6352 7600 9094 9507 9938 10176 13024 11594 12003 13856 15886 17031 17038 15775 14029 ) ) Pennit to drill -~, ~. -- UNOCAL8 South Ninilchik Pearl Well No.1 Permit to Drill 47 of 48 ~,.- UNOCAL8 Unocal Corporation ~ P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 Dan Williamson Friday January 5, 2002 Drilling Manager Ms. Cammy Taylor, Commissioner AOGCC 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill South Ninilchik PEARL Well No.1 East Side, Kenai Penensula Dear Chairperson Taylor, Enclosed is an Application for Permit to Drill (Form 10-401) for the Unocal South Ninilchik Prospect, Pearl Well No.1. Pearl No.1 is proposed as an exploration gas well targeting the Tyonek sands as the primary objective in the South Ninilchik Prospect. The well will be drilled as a straight hole. The Tyonek sands being targeted fall inside the Unocallease and the well does not encroach on other property owners. . Unocal proposes to utilize a 12" diverter line for the drilling of the 12-1/4" Surface hole. Analysis of the offset wells indicates that no gas flow or pressure problems were encountered while drilling surface hole. The Pearl No.1 proposed surface casing depth is 1800' RKB, and is about 400 feet into the Beluga formations. An anticipated stratigraphy chart is enclosed with the application for Permit to Drill. The anticipated start date for this well work is February 7th, 2001. If you have any questions, please do not hesitate to call Jim Mosley at 263-7679. ~;.r~}y 1)J n nnMlIt '~am~4 Drilling Manager RECE IVED JAN 0 7 2002 Pennit to drill Page 1 of 47 Alaska Oil & Gas Cons. Commission Ancl1orage .. UNOCAL8 ~ South Nh._tchik Pearl Well No.1 Permit to Drill TABLE OF CONTENTS PERMIT TO DRILL FORM 10-401........................................................................................................... 3 SURVEYORS PLAT......... ..... ....... ............ ............ ""'" ........................ "'" ....... ................... ......................... 4 LOCATION MAP WITH OFFSET WELLS ............................................................................................. 5 TO POGRAPHI C MAP. ................ ......................................... ....... ................. ..................... ............ ............. 7 TRACT MAP................................................................................................................................................ 8 PAD ACCESS AND ROAD PLAN ............................................................................................................. 9 PAD SITE CONSTRUCTION PLAN .""""""""""""""""""""""""""""""""""""""""""""""""""" 10 PAD AND PIT CONSTRUCTION DETAILS """""""""""""""""""""""""""""""""""""""""""'" 11 D RILLIN G PROCEDURE .. .......... """""" """""" ""'" """"""""'" ..... .............. .......... ............ ............ ..... 12 DAYS VERSUS DEPTH PLAN ................................................................................................................ 14 WELL BORE SCHEMATIC ""'" ....... """""""'" ....... ............ ....... ...................... ...".. ..... """""""'" ......... 15 STRATIGRAPHIC TOPS OF FORMA TIONS....................................................................................... 16 HAZARD ANALYSIS FOR APD ............... ......... ....."..... ................. ............................. ......... .......... """'" 17 BOTTOMHOLE PRESSURE INFO RMA TI ON ..................................................................................... 18 LEAK OFF TEST PR OCED URE ......... ........ .......................... ....... ....... ............ """"""'" """""""""""'" 20 DIVER TER AND BOP SPECS ................................................................................................................. 21 CAS IN G DESIGN. """""""""'" """"""" "'" ............ ......... ..... """"""" """""" """""""'" "'" """""" ........ 22 CAS IN G PROGRAM SUMMARY....... ................. ....... ....... ....... ............ """""" ..... """'" "'" ........" """'" 23 CEMENT VOLUME CALCULA TI 0 N S """" ............ """"""" ................. ....... ....................................... 24 DIVERTER STACK UP DRAWING ..................................................R:J;CE.I.VED............ 25 BOP STACK DRA WIN G .............................................................................JAN..+¡...7":ZfJFì"j.................. 26 CHOKE MANIFOLD DRAWING ................................................AlaskaGiI&~~'ccrmm;YSiö,r""""" 27 MUD PIT LAYOUTS.......... """""" ""'" """""" ""'" ""'" "'" "'" ......." "'" ......... ............... """"""""""""" 28 MUD PROGRAM.... """'" ........".... ""'" """"""""'" """""" .......,.... ......." """""""'" ......,.. ...., """"""""" 31 SALINITY CALCULA TI 0 N S ... "'" """"""" ..... "'" """'" ..... """""""" ..... ""'" ....... """""" ....... .............. 37 SHALLOW GAS HAZARDS AND SEISMIC VELOCITY ANALYSIS """"""""""""""""""""""" 38 Pennit to drill 2 of 48 "........., ,.-. FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED 1031548 04-JAN-02 2004726 DISCOUNT NET 100.00 03-JAN-02 PERMITTODRILL PEARL 1 01023000003 100.00 RECEIVED JAN 0 7 20)2 Alaska Oil & Gas Cons. Conmission Anchorage FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK 100.00 100.00 CITIBANK DELAWARE A Subsidiary of Citìcorp ONE PENN'S WAY NEW CASTLE, DE 19720 62-20 31f Union Oil Company of California Accounts Payable Field Disbursing 2004726 UNOCAL.G Pay Hundred Dollars And 00 Cents********1!.'*1!.'******1!.'********* Date04-JAN-02 CheckAtJ~t1!.'*lOO. 00 To the STA['~OFALASKA order ALASKA OIL 6r GAS CONSERVATION of COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States Void after six months from above date. -+:: .<- 11'2001.. 72 bu' 1:0 ~ ~ ~On2ngl: ~ g ~ ¡. a ¡. ~ 7 II' CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDRILL EXPLORAT, INJECTION WELL INJECTION WELL REDRlLL ..... --- .-- TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BEINCLUDEDINT~NnTTALLETTER WELL NAME (~( =# I CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new well bore segment of existing well -------" Permit No, API No. . . Production should continue to be reported as a function of the original API number stated above. . (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR r.40SAL CÙ"NO Annular disposal has not been requested. . . ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . <-) YES ANNULAR DISPOSAL THIS WELL Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS L-J YES + SP A CIN G7PTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. e"",-V'"",.\", <xJ,,"'" ~S,<:»S' ~\(,,\\~t,) -\0 (If) <43 ris r""~.LýL~~ '1h \ \, \;>, I,," I., "" .." I \;¡" ~\",-,"",- ,\ \ N< 2"~' ". 'U ' ~'P( ""E.xF{lf"1~~" ¿ja4 ~~( b-J drl.(~ ZC>O Templates are located m drive\jody\templates fr~ ~lc.i~,- d#-/ ./. 41 U~ ¿J~ I ~ md/'ð~ ~ ~ (j ~ - r- ZOO ---ïÞ .(I a., 724 - ~.~ ~ ~/ =--r- . D5J. t. ~ ú'ZJ~~ ~ u.-. ~-I J ~ W; ð7 tÀv .~~ . ~ ~.k ~-fr 1I(u4'/c. ~ ~ M/l not h ~ ú, ~ '?J .£b-.- ~ Drilling Fluids Recap UNOCAL OIL & GAS PEARL #1 NINILCHIK February 17, 2001 Prepared by: J. Brown, F. Slater -, UNOCALe ~ ~ M-I LLC. ONE-TRAX DRilliNG FLUIDS DATA MANAGEMENT SYSTEM Comments: Type Size in Depth ft TVD ft Hole MaxMW Mud 1 in Ib/gal Mud 2 Drilling Problem . Days Cost $ ------------------------------------------------------------------------------------------ 7 Casing 9.625 1790 1790 12.25 9.30 Spud Mud Casing 7 7920 7920 8.5 10.20 Oil-based Total Depth: 7920 ft TVD : 7920 ft Water Depth: ft Drilling Days: 23 Total Mud Cost: $ 192897.82 ~ ~ PRODUCT SUMMARY ,-" Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Field/Area: NINILCHIK Description: Location: WATER-BASED MUD SIZE AMOUNT 2/16/2002 - 3/11/2002, 105 - 7920 ft SUMMARY OF PRODUCT USAGE FOR INTERVAL 1 - ENGINEERING SERVICE 1 EA 22 2 - Flo-Vis Plus 25 LB BG 8 3 - Caustic Soda 50 LB BG 10 4 - M-I BAR (LINED BAG) 100 LB BG 112 5 - KD OILFIELD (SOLAR) 80LBBG 5 6 - M-I GEL EXPORT 100 LB BG 150 7 - POL YPAC SUPREME UL 50LBBG 32 8 - NUT PLUG-M 50LBBG 3 9 - GELEX BENT EXTENDER 2 LB BG 19 10 - SODIUM BICARBONATE 50 LB BG 20 11 - DESCO CF 25 LB BG 16 12 - SOL TEX 50 LB BG 12 13 - RESINEX 50LBBG 58 SUB TOTAL: TAX: WATER-BASED MUD TOTAL COST: UNIT COST PROD COST ($) ($) 625.00 13750.00 189.00 1512.00 27.95 279.50 12.70 1422.40 13.71 68.55 13.71 2056.50 152.70 4886.40 19.90 59.70 11.90 226.10 19.08 381.60 43.90 702.40 73.50 882.00 62.81 3642.98 29870.13 0.00 29870.13 OIL-BASED MUD SIZE AMOUNT UNIT COST PROD COST ($) ($) 1 - ENGINEERING SERVICE 1 EA 29 625.00 18125.00 2 - M-I BAR (LINED BAG) 100 LB BG 1439 12.70 18275.30 3 - M-I GEL EXPORT 100 LB BG 13.71 13.71 4 - LOWATE 50LBBG 60 10.48 628.80 5 - CLEAN-UP 55 GA DM 2 438.68 877.36 6 - CALCIUM CHLORIDE 80 LB BG 247 48.88 12073.36 M-I LLc. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 021223012 ,~ ,,-.,. ~ PRODUCT SUMMARY Operator: UNOCAL Field/Area: NINILCHIK Well Name: PEARL 1 Description: Contractor: H & RlKUUKPIK Location: SUMMARY OF PRODUCT USAGE FOR INTERVAL OIL-BASED MUD SIZE 2/16/2002.3/11/2002, 105.7920 ft AMOUNT UNIT COST PROD COST ($) ($) 7 - LIME 50 LB BG 58 15.60 904.80 8 - CLAYTONE 2 (VG-69) 50 LB BG 106 69.50 7367.00 9-VERSACOAT 55 GA DM 10 578.18 5781.80 10 - VERSAMOD 55 GA DM 2 676.00 1352.00 11-VERSAIROL 50 LB BG 8 34.80 278.40 12 - VERSAWET 55 GA DM 9 390.00 3510.00 13 - MAPCO 200 1 GACN 59771 1.57 93840.16 SUB TOTAL: 163027.69 TAX: 0.00 OIL-BASED MUD TOTAL COST: 163027.69 TOTAL MUD COST FOR INTERVAL: 192897.82 M-I u..c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 021223012 ~ Water-Based Mud Products I-Common Chemicals 2-Dispersants 3-Englneering 4-Lost Circ Material 5-Lubricant 6-Visc/Fluid Loss 7-Weight Material Water-Based Mud Total Cost: Total Mud Cost for Interval: S M-I L.L.C. ON E- TRAX Well Name: PEARL 1 Field/Area: NINILCHIK Description: Location: BREAKDOWN OF COST BY PRODUCT GROUP 2/16/2002 - 3/11/2002, Water-Based Mud 2.4~.4% 4.8% 0.2%0% S 729.65 % % 2.4 0.4 2.4 0.4 46.0 7.1 0.2 0.0 3.0 0.5 41.3 6.4 4.8 0.7 100.0 15.5 702.40 13750.00 59.70 882.00 12323.98 1422.40 29870.13 192897.82 Oil-Based Mud Products l-Common Chemicals 2-Engineering 3-Lubrlcant 4-VisclFluid Loss S-Weight Material Oil-Based Mud Total Cost: DRILLING FLUIDS DATA MilNAGEMENT SYSTEM 0 - 7920 ft Oil-Based Mud 8.5% 11.1% 57.6% S 13855.52 18125.00 93840.16 18302.91 18904.10 163027.69 (;ost Analysis 11.2% ) % % 8.5 7.2 11.1 9.4 57.6 48.6 11.2 9.5 11.6 ) 100.0 84.5 June 03, 2002 ~ Operator: Well Name: Contractor: Date DepthlTVD Activity Mud Type Hole Size Circ Volume Flow Rate Circ Pressure Avg ROP Sample From Flow Line Temp Mud Weight Funnel Viscosity PV YP R600/R3001R200 R1O0/R61R3 lOs/1Om/30m Gel API Fluid Loss HTHP Fluid Loss Cake API/HT Solids Oil/Water Sand MBT pH AlkalMud (Pm) Pf/Mf Chlorides Hardness Ca Daily Mud Cost Cuml Mud Cost Sales Engineer Products Used ...--" ----. DRILLING FLUIDS SUMMARY UNOCAL Field/Area: NINILCHIK PEARL 1 Description: H & RlKUUKPIK Location: 2/16/2002 2/17/2002 2/18/2002 2/19/2002 2/20/2002 2/21/2002 ft 105/l05 435/435 1800/l800 1800/1800 1800/1800 1800/1800 ~IG UP TO SPill DRILLING :;ULATE FOR 1 lENT SURFACE N U BOP'S PUDP SPUD MUD SPUD MUD SPUD MUD SPUD MUD GEL/WATER M GEL/WATER M in 12.25 12.25 12.25 12.25 12.25 8.5 bbl 360 497 863 794 588 587 gallmi~ 0 793 793 0 0 356 PSI 0 1400 2200 0 0 0 ftIhr 0 0 0 0 0 100 Pit Pit Pit Pit PIT PIT of 62 85 85 Ib/gal 8.6(á1 OF 8.9(á1 of 9.3(á)82 of 9.2(á)85 OF 9.2(á)50 of 9.2(á)50 of s/qt 48 50 80 48 50 40 cP 9 17 26 18 12 10 Ib/l00ft2 9 16 30 .11 19 14 27/18/15 50/33/25 82/56/45 47/29/20 43/31/20 34/24/16 10/5/4 17/5/4 32/11/9 12/3/2 12/413 11/3/2 Ib/l 00ft2 4/13/28 7/16/25 10/26/36 2/4/l2 3/10/l2 3/9/l I cè/30 min NC 18;8 12.8 16.4 9.8 11.2 cc/30 min 1/32" 2/ %Vol 3.5 9.3 7 %Vol 0/96.5 0/90.7 0/93 %Vol 1/4+ I TR . Iblbbl 9.5 9.0 9.0 0.15/0.3 0.1510.65 0.0510.3 0.0510.4 0.1/0.4 0.1/0.35 mg/l 400 1500 900 800 . 800 120 120 40 20 20 40 1875.00 13406.65 ORREST/JIM BRt ENG / 3 $ 4744.65 1793.50 2319.50 $ . 4744.656538.15 8857.65 . 1M BRO/FORRES' 1M BRO/FORRES' 1M BRO/FORRES' ENG j.' 6 '. GêlI 35 NUT-MEDI 3 Caustic / 2 GELEX I 3 GELEX I 5 GeLl65 .ENGI2. . ENGI2 GELEX I 4 Caustic I I Caustic I I . Gel 145 PAC I 2 2049.00 625.00 10906.65 11531.65 1M BRO/FORRESl ORREST/JIM BR( DESCOI 2 ENG I .1 ENG I 2 BAR /56 REMARKS 2/16/2002: RIG UP TO SPUD. 2/17/2002: SPUD 1800 HRS ON 2-17-02. 2/1812002: DRLGTO 1800'. PUMP 50bbl HI-VIS SWEEP. SHORT TRIP TO COLLARS. TRIP OK& NO FILL. PUMP 50 bbl HI-VIS SWEEP, CBU & POOl 2/19/2002: RUN 9 5/8" 47 LBIFT CSG TO 1800'. REDUCE YP ON MUD & CEMENTED CSG. 2/20/2002: WOC. ND. NU BOP'S. 2/21/2002: TEST BOP'S. PU DP. M-l u..c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 021223012 r:J Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Date DepthlTVD Activity Mud Type Hole Size Circ Volume . Flow Rate Circ Pressure AvgROP Sample From Flow Line Temp Mud Weight Funnel Viscosity PV yp R600/R3001R200 RIOO/R61R3 lOs/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake API/HT Solids Oil/W ater Sand MBT pH Alkal Mud (Pm) Pf/Mf Chlorides Hardness Ca in bbl gal/min psi ft/hr OF Ib/gal s/qt cP Ib/100ft2 lb/l OOft2 cc/30 min cc/30 min 1/32" %Vol .%Vol %Vol . Iblbbl .~. /'"'. DRILLING FLUIDS SUMMARy ft Field/Area: NINILCHIK Description: Location: 2/22/2002 2/22/2002 2/23/2002 2/23/2002 2400/2400 1820/1820 3575/3575 2800/2800 DRLG DRLG DRLG DRLG GEL/WATER M GELlW A TER M GEL/WATER M GEL/WATER M 8.5 8.5 8.5 8.5 513 513 777 777 378 378 423 423 1300 1300 2000 2000 100 100 100 100 PIT PIT PIT PIT 78 7I 94 85 9.1 +(ã)75 of 8.9+(ã)70 of 9.4+(ã)87 of 9.4(ã)78 of 44 41 46 48 9 7 10 10 10 10 11 12 28/19/15 24/17/13 31/21/15 32/22/16 11/4/3 10/3/2 11/3/2 11/4/3 3/9/10 3/8/10 3/7/8 3/7/8 7.3 11.8 5.6 5.8 îng!l <2/ 1/ >2/ 6 4 7 7 0/94 0/96 0/93 .0/93 TR TR TR TR 17.5 15.0 17.5 17.5 9.5 10.0 9.5 9.0 .35 .4 0.2/0.45 0.25/0.5 0.2/0.7 0.15/0.6 1100 1200 1000 1000 40 40 60 40 2/24/2002 4900/4900 DRLG LSND MUD 8.5 961 445 2300 100 PIT 101 9.8+(ã)90 of 46 13 10 36/23/17 11/3/2 3/7/8 6.0 9 0/91 TR .20 . 9.5 0.2/0.8 800 60 Daily Mud Cost CuI111 Mud Cost Sales Engineer Products Used 4409.82 4865.24 17816.47 22681.71 ORREST/JIM BR( ORRESTIJIM BR( ORRESTIJIM BR( 'ORRESTIJIM BRC ENGI2 ENG/2 Flo-Vis / 4 Caustic / 2 PAC 16 . PACI12 Bicarb / 10 DESCO / 5 DESCOJA RES 124 Asphalt / 5 RES 112 2/24/2002 4100/4100 DRLG LSND MUD 8.5 961 445 2300 100 PIT 95 9.6(ã) 88 of 47 11 11 33/22/16 11/3/2 3/7/8 5.8 <2/ . 7 0/93 TR 11.5 9.0 .4 0.15/0.7 .900 40 7188.42 29870.13 ORREST/JIM BR( ORREST/JIM BR( ENG / 2 Flo-Vis / 4 Caustic / 4 BAR/56 SaltJ5 Gel / 5 PAC 112 GELEX / 7 Bicarb r 10 DESCO / 5 Asphalt / 7 RES/22 REMARKS 2/22/2002: PU 4" DP TO BE ABLE TO DRILL TO 5000'. STAND BACK. MU BHA; RIH. TEST CSG. DRL CMT & FLOAT. TEST FORM TO 12.5PPG. DRLG. 2/23/2002: DRL TO 2783'. SH TRIP TO SHOE. DRL AHEAD. 2/2412002: DRL TO 3809'. SH TRIP TO 2000'. DRL AHEAD. MAKE PREPARATIONS FOR SWITCHING TO OBM. M-I LL.c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 2 021223012 ~ Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Date Depth/TVD Activity Mud Type Hole Size Circ Volume Flow Rate Circ Pressure Avg ROP Sample From Flow Line Temp Mud Weight Funnel Viscosity PV -yp R600/R300/R200 RIOO/R61R3 IOs/10m/30m Gel API Fluid Loss HTHP Fluid Loss Cake API/HT Unc Ret Solids Correct Solids Oil UncorrWater Oil/Water Ratio Cl Whole Mud Salt Lime E-Stability in bbl gal/mill psi ft/hr OF Ib/gal s/qt cP Ib/l00ft> Ib/lOOft2 cc/30 mill cc/30 mill 1/32" %Vol %Vol %Vol %Vol --mg/) %Wt Ib/bbl Daily Mud Cost CuffilMudCost Sales Engineer Products Used ---- ~ DRILLING FLUIDS SUMMARY ft 2/2512002 540015400 DRLG OBM 8.5 962 405 2800 100 PIT 93 1O.2Cá185 OF 85 31 21 83/52/40 29/16/15 23/27/29 4.8 1<2 9 8;2 77 14 85/15 24000 21.15 .65 1450 2/2612002 6257/6257 DRLG OBM 8.5 1180 396 2800 100 PIT 91 10.lCá185 of 141 32 28 92/60/47 33/18/17 24/32/33 Field/Area: NINILCHIK Description: Location: 212712002 2/28/2002 3/1/2002 3/1/2002 6910/6910 7257/7257 7341/7341 7341/7341 DRLG DOH fCORE BE CORING I CBU CORING I CBU OBM OBM OBM OBM 8.5 8.5 8.5 8.5 1229 1239 1257 1257 401 401 267 267 3300 3300 1800 1800 40 40 0 0 Pit Pit Pit Pit 118 120 NA 100 lO.lCá198 OF 1O.2Cá1115 of 1O.3Cá180 of 1O.1Cá180 of 126 137 183 126 31 31 32 28 19 18 22 15 81/50/39 80/49/38 86/54/43 71/43134 28/15/14 26/13112 32/18/17 23/12/11 21/29/30 22/28/31 22/27/32 19/26/30 4.8 1<2 5.0 5.0 1<2 II 10.5 9.2 73 75 14.5 82/18 82/18 83/17 31000 31000 31000 23.27 23.27 24.44 .39 .39 .39 1610 1600 1422 84/16 24000 21.15 .65 1540 84/16 27000 23.18 - .65 1585 $ $ 13998.58 2383.60 10701.00 106358.10 108741.70 119442.70 ORREST/JIM BR( 1M BRO/FORRES' 'ORREST/JIM BRC ENG /2 ENGI 2ENG I 2 BAR I 112 CACL I 20 BAR I 112 LOWTI 60 Lime I 10 CACL I 20 Lime I 2 VG69 I 12 VG69 14 COAT 11 COAT I 1 WET I 1 - WET I] M200 13343.2 M200 I 6000 6252.18 - 125694.88 ORREST/JIM BR( ENG 12 BAR I 46 M200 / 2814 ORREST/JIM BR( 62489.39 92359.52 ORREST/JIM BR( ENGI2 BAR I 784 Gel II CACL I 120 Lime /12 VG69 I 90 COAT/-6 MOD I 2 WET/3 M200 I 21000 REMARKS 2/25/2002: DRL TO 5068'. PUMPIROTATEOUTTO 3800'. PUMP OUT TO SHOE; LOOKED GOOD. PREP TO DISP. DISPTO OBM. DRL TO 5400 AT 2400. 2/26/2002: DRL TO 6137. SH TRIP TO PU DP. 2/27/2002: DRLG TO 6628'. POOH TO 6415' & WORK ON TOP DRIVE. RIH & DRILLED AHEAD. 2/28/2002: DRLG TO CORE PT @ 7257'. CBU. PUMP DRY JOB. POOH. 3/1/2002: RIH w CORE #1. TAG FILL @ 7235'. WASH FILL 7235'-7257' (hole trying to pack off). CORING 7257' - 7341.5' M-I u..c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 3 021223012 ,-.. --\ r:J DRILLING FLUIDS SUMMARY Operator: UNOCAL Field/Area: NINILCHIK Well Name: PEARL1 Description: Contractor: H & RlKUUKPIK location: Date 3/2/2002 3/2/2002 3/3/2002 3/3/2002 3/4/2002 3/4/2002 Depth/TVD ft 7419/7419 7419/7419 7700/7700 7758/7758 7985/7985 7985/7985 Activity DRLG DRLG DRLG DRLG DRLG DRLG Mud Type OBM OBM OBM OBM OBM OBM Hole Size in 8.5 8.5 8.5 8.5 8.5 8.5 Cire Volume bbl 1234 1234 1288 1288 1376 1376 Flow Rate gaVmin 334 334 401 401 401 401 Cire Pressure PSI 2200 2200 2850 2850 2800 2800 Avg Rap ft/hr 0 0 0 0 0 0 Sample From Pit PIT Pit Pit Pit Pit Flow Line Temp of Trip 100 117 114 112 114 Mud Weight Ib/gal 1O.1@}80 OF 10.2 @}1O0 of 10.1@}80 of 10.1 @}85 of 1O.1@}80 of 1O.1@}85 of Funnel Viscosity s/qt 126 131 106 108 97 97 PV cp 28 25 24 23 23 24 yp Ib/l00ft2 15 16 15 ' 15 13 12 R600/R300/R200 71/43/34 66/41/31 63/39/30 61/38/29 59/36/28 60/36/27 R1O0/R61R3 23/12/11 ' 22/12/11 20/9/8 20/10/9 19/9/8 20/9/8 lOs/10m/30m Gel Ib/1 OOfe 19/26/30 20/27/29 11119/28 16/26/30 16/28/29 16/28/30 API Fluid Loss ccl30min HTH}> Fluid Loss ec/30 min 5 5.2 5.4 5.6 6.0 6.0 Cake APIIHT ' '1/32" 2/ /2 Une Ret Solids %Vol 10 11 10.5 10.5 Correct Solids %Vol ' 10. ' 10.5 Oil %Vol 76 75 77.5 77.5 Uricorr Water %Vol 12 12 Oil/Water Ratio 84/16 84/16 87/13 87/13 ClWholeMud mgll 30000 29000 26000 26000 Salt %Wt 1 24.48 25.32 25.32 Lime 'lblbbl 1.82 1.95 1.95 E-Stability 1405 1690 1660 4768.94 , 134749.68 ' ORRESTIJIM BR( 'ORRESTIJIM BRC , ENGI2 Lime / 10 , M200 /2142 8080.74 142830.42 ORRESTIJIM BR( ENG / 2 BAR / 55 Lime /4 VTROL / 8 , WET I 2 M200 / 3192 ORREST/JIM BR( Daily Mud Cost Cuml Mud Cost Sales Engineer Products Used $ $ 4285.86 129980.74 " ORRESTIJIM BR( . ENG /2 ' Lime / 20 COATI 2 WET / 1 M200/ 750 ORRESTIJIM BR( REMARKS 3/2/2002: CBU. PUMP DRY JOB & POOH w CORE BBL. CLEAN RIG FLOOR. LAY DN MUD MOTOR. PU ROTARY ASSM. 3/3/2002: DRLG. 3/4/2002: DRLGTO 7808'. REPAIR TOP DRIVE. POOH TO 7110' (PULLED40KOVER@7606-7518'&7469'.)TOPDRV. RIH OK. DRLG. TOP DRV. M-I LLc. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 021223012 4 --\ ~ DRILLING FLUIDS SUMMAR'f Operator: UNOCAL Field/Area: NINILCHIK Well Name: PEARL1 Description: Contractor: H & RlKUUKPIK Location: Date 3/5/2002 3/5/2002 3/6/2002 3/6/2002 3/7/2002 3/8/2002 Depth/TVD ft 8000/8000 8000/8000 8000/8000 8000/8000 8000/8000 8000/8000 Activity LOGGING LOGGING Cementing Cementing Cementing TRIP Mud Type OBM OBM OBM OBM OBM OBM Hole Size in 8.5 8.5 0 0 0 6 Circ Volume bbl 1354 1354 1318 1318 1327 921 Flow Rate gal/mi~ 0 0 0 0 0 231 Circ Pressure PSI 0 0 0 0 0 1500 Avg ROP ft/hr 15.5 15.5 0 0 0 0 Sample From 105 Pit Pit Pit Flowline Flowline Flow Line Temp of 80 60 Mud Weight Ib/gal 10.1~70 OF 1O.1~70 of 10.2~60 of 10.2~60 of 10.2 ~80 of 1O.2~60 OF Funnel Viscosity s/qt 136 138 138 140 163 153 PV cP 23 25 23 27 27 28 yp Ib/l00ft2 13 12 13 16 16 15 R600/R300/R200 59/36/28 62/37/30 59/36/28 59/36/28 70/43/37 71/43/34 RI00/R6/R3 19/9/8 21/10/9 19/9/8 19/9/8 27/11/10 23/12/11 IOs/1 Om/30m Gel Ib/l00ft2 16/28/30 16/28/30 16/28/30 17/29/31 18/30/32 19/33/35 API Fluid Loss dc/30 min HTHP Fluid Loss . cc/30 min 5.0 5.6 Cake APIIHT 1/32" /2 /2 Unc Ret Solids %Vol 10.5 11 11 10 11 Correct Solids %Vol 10. 10 Oil %Vol 78 76 Uncorr Water %Vol 12 13 Oil/Water Ratio 87/13 86/14 87/13 87/13 87/13 85/15 ClWhole Mud Irig/1 26000, 26000 . 25500 26000 25000 27500 Salt %Wt 25.32 24.56 24.96 24.59 24.87 Lime Iblbbl 1.95 1.95 1.95', 1.69 1.04 E-Stability 1682 1660 1678 1682 1638 1591 Daily Mud Cost Cuml Mud Cost Sales Engineer Products Used $ $ 3062.40 145892.82 ORREST/JIM BR( ENG /2 BAR / 112 WET /1 ORREST/JIM BR( 3647.36 . 149540.18 ORREST/JIM BR( 'ORREST/JIM BRC ENGT2 BAR / 168 'M200'F.168 6137.56 ;155677.74 ORREST/JIM BR( ENG /2 BAR/50 CACL r 87 2436.92 158114.66 ORREST/JIM BR( ENG / 2 M200 / 756 REMARKS 3/5/2002: DRLGTO 8000'TD. SHORT TRIP TO 7110' OK. RIH & POOH TO LOG. LOGGER'S DEPTH - 8000'. LOGGING OK. 3/6/2002: LOGGING WITH C-SA T SCHLUMBERGER TOOL. LD BHA. CHANGE TO 7" RAMS & TEST. RUN 7" CSG. 317/2002: running 7" casing and cementing 3/812002: FINISH 2nd STAGE CEMENT JOB. TEST PACK OFF & NECK SEALS. RIH 5033' & TEST CSG TO 3000psi. DRLG DV TOOL. M-I u.c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 021223012 5 r:J in bbl gal/min psi ftJhr OF Ib/gal s/qt cP Ib/IOOft2 Ib/1O0ft2 cc/30 min cc/30 min . .1132" %Vol %Vol %Vol %Vol .----- ~. DRILLING FLUIDS SUMMAR., ft 3/8/2002 5035/5035 TRIP OHM 6 921 231 1500 0 Flowline 65 1O.2@i60 of 149 28 14 70/42/33 22/11/îO 18/29/33 5.6 Field/Area: NINILCHIK Description: Location: 3/9/2002 3/9/2002 3707/3707 7920/7920 RIH W/PACKEF RIH W/PACKEF OHM OHM 0 0 1336 1336 0 0 0 0 0 0 Pit Pit 9.7@i65 OF 9.3@65 of 168 156 26 25 16 15 68/42/33 65/40/32 22/12/11 . 21/10/9 18/30/32 14/24/28 6 6.4 9 7 11 .. mgll %Wt Iblbbl 84/16 27000 23.18 1.43 . 1410 85/15 28500 24.16 1680 84/16 26000 21.34 .. 1.69 1612 Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Date Depth/TVD Activity Mud Type Hole Size Circ Volume Flow Rate Circ Pressure AvgROP Sample From Flow Line Temp Mud Weight Funnel Viscosity PV yp R600/R300/R200 R 1 00/R6/R3 lOs/lOrn/30m Gel ' API Fluid Loss HTHP Fluid Loss Cake API/HT Unc Ret Solids Correct Solids Oil UncorrWater Oil/Water Ratio CIWholeMud Salt Lime E-Stability Daily Mud Cost CumlMud Cost Sales Engineer Products Used $ 26834.72 . 184949.38 . ORREST/JIM BR( ORREST/JIM BR( ORREST/JIM BR( . ENŒ12 .. M200 16296 REMARKS 3/9/2002: DISPLACE OBM WITH BASE OIL. POOH WI 4" DP. RIH W/3 1/2" TUBING & SET PACKER@ 3707. M-I u..c. DRILLING FLUIDS DATA MANAGEMENT SYSTEM 6 021223012 ,~ ~ ~ HYDRAULICS SUMMARY Date Depth Days Since Spud *RHEOLOGICAL PROPERTIES Mud Wt Ib/gal Plastic Visc cp Yield Point Ib/IOOft2 3-rpm Rdg Fann deg np Value Kp Value naValue KaValue *FLOWDATA Operator: UNOCAL Field/Area: NINILCHIK Well Name: PEARL 1 Description: Contractor: H & RlKUUKPIK Location: 2/16/2002 12/17/2002 I 2/18/2002 I 2/19/2002 i 2/20/2002 105 ¡ - 435 I 1800 I 1800 ' 1800 I 2 3 4 ft 2/21/2002 I 2/22/2002 I 2/23/2002 1800 i 2400 : 3575 5 6 7 Ib.s^nlIOOft2 8.6 8.9 9.3 9.2 9.2 9.2 9.1+ 9.4+ 9 17 26 18 12 10 9 10 9 16 30 11 19 14 10 II 4 4 9 2 3 2 3 2 .585 .5995 .5502 .6966 .4721 .5025 .5594 .5619 .5002 .8377 1.9328 .4017 1.7417 1.1153 .6191 .6739 .2613 .4126 .3618 .511 .3953 I .4862 .3705 .4862 2.7868 2.1772 5.3227 .9273 1.6796 I .9656 1.749 .9656 0 0 0 356 423 0 0 0 0 2000 494 Ib.s^nlIOOft2 * * * * 22 18 * * * 53 63 91 * * * .93 l.l 1.6 * * * 176 187 209 298 332 430 243 258 289 * * * 257 263 253 * * * 2224 2438 2951 CritRe * * * 2782 2704 2700 *DRlLL PIPE ANNULUS, . Velocity : . 'ft/nîin * 145 145 * * 167 Critical Vel ,ft/nîin * 252 377 * * 201 'ReYflolds Nijmbet * 1032 526 * * 1830 Crit Re (Larn -,Trap) * 2649 2716 * * 2700 *HOLE CLEANING Slip yel()City ft/nîin * 22 15 * * 30 26 30 Risingyel()City . . ft/nîin * 123 130 * * 213 123 137 Lifting Capacity .' % * 85 90 * * 88 83 82 Cutting Cone .% * 0.0 0.0 * * 1.58 1.57 1.41 Penetration Rate ft/h 0 0 0 0 0 100 100 100 CASING SHOE PRESSURES ECD Ib/gal * 9.78 9.58 * * 9.38 9.27 9.56 ECD+Cuttings Ib/gal * 9.78 9.58 * * 9.56 9.45 9.72 TOTAL DEPTH PRESSURES ECD Ib/gal * 9.14 9.58 * * 9.38 9.29 9.59 ECD+Cuttings Ib/gal * 9.14 9.58 * * 9.56 9.47 9.75 M-I u.c. 021223012 DRILLING FLUIDS DATA MANAGEMENT SYSTEM ----.. ~ .~ ~ HYDRAULICS SUMMARY Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK 2/24/2002 ! 2/25/2002 I 2/26/2002 ft 4900 5400 6257 8 9 10 Date Depth Days Since Spud *RHEOLOGICAL PROPERTIES Mud Wt Ib/gal PlasticVisc cP Yield Point Ib/1O0ft2 3-rpm Rdg Fann deg np Value Kp Value na Value KaValue *FLOWDATA Flow Rate Pump Pressure Pump Ib.s^nlIOOft2 Ib.s^nll00ft2 gaVltlin 9.8+ 13 10 2 .6464 .4358 .4862 .9656 10.2 31 21 15 .6746 .8262 .188 11. 778 10.1 32 28 17 .6167 1.3681 .1892 13.3232 Field/Area: NINILCHIK Description: Location: 2/27/2002 i 2/28/2002 ! 6910 7257 11 12 3/1/2002 7341 13 10.1 31 19 14 .696 .6952 .1977 10.8208 10.2 31 18 12 .7072 .6352 .2205 . 8.9359 i 10.3 32 22 17 .6714 .8754 .1804 13.5153 3/2/2002 ¡ 3/3/2002 . 7419 7700: / 14 15--1 10.1 28 15 11 .7235 .5037 .2103 8.328 334 2200 429 10.1 24 15 8 .6919 .5563 .2613 5.5736 401 2850 667 18 13 12 11 11 9 II 12 110 86 80 83 84 25 48 83 1.94 1.52 1.41 1.46 1.48 .44 .84 1.46 220 200 196 198 198 132 165 198 Impact Force 496 428 405 415 419 188 288 415 DRILL COLLARS ANNULUS Velocity . ftlmin 304 277 270 274 274 182 228 274 Critical Vel 247 421 455 416 400 441 375 350 Reynolds Number 3322 1270 1060 1269 1357 548 1103 1706 Crit Re (Lam- Tran) 2584 2546 2625 2516 2501 2550 2479 2522 *DRlLL PIPE ANNULUS Velocity. 176 160 156 158 158 105 132 158 Critical Vel 195 390 421 385 366 410 344 314 Reynolds Number 2060 538 450 545 600 230 481 794 Crit Re (Lam ~Tran) 2584 2546 2625 2516 2501 2550 2479 2522 *HOLE CLEANING Slip Veloeity 29 13 12 13 13 12 14 16 Rising Velocity 147 147 144 145 145 93 117 142 Lifting Capacity 84 92 92 92 92 89 89 90 Cutting Cone 1.32 1.32 1.34 0.53 0.54 0.0 0.0 0.0 Penetration Rate ftIh 100 100 100 40 40 0 0 0 CASING SHOE PRESSURES ECD Ib/gal 9.96 10.72 10.69 10.6 10.66 10.83 10.49 10.44 ECD+Cuttings Ib/gal 10.11 10.86 10.83 10.66 10.72 10.83 10.49 10.44 TOTAL DEPTH PRESSURES ECD Ib/gal 9.98 10.75 10.71 10.61 10.67 10.85 10.5 10.45 i ECD+Cuttings Ib/gal 10.12 10.89 10.85 10.67 10.73 10.85 10.5 10.45 I 021223012 DRILLING FLUIDS DATA MANAGEMENT SYSTEM i M-I L.Lc. 2 267 1800 280 .----. ---- ~ HYDRAULICS SUMMARY Dåte' . Depth Days Since Spud *RHEOLOGICAL PROPERTIES Mud Wt Ib/gal Plastic Vise cp Yield Point Ib/l 00ft2 3-rpm Rdg Fann deg np Value Kp Value na Value Ka Value *FLOW DATA Flow Rate Operator: UNOCAL Well Name: PEARL 1 Contractor: H & R/KUUKPIK 3/4/2002 ft 7985 16 3/5/2002 8000 17 3/6/2002 8000 18 Field/Area: NINILCHIK Description: Location: ! 3/7/2002 3/8/2002 i 8000 8000 19 20 3/9/2002 3707 21 Ib's^nlIOOft2 10.1 10.1 10.2 10.2 10.2 9.7 23 23 23 27 28 26 13 13 13 16 15 16 8 8 8 10 II II .7127 .7127 .7127 .703 .7235 .6951 .4509 .4509 .4509 .5722 .5037 .587 .2467 .2467 .2467 .2833 .2103 .1977 5.7082 5.7082 5.7082 6.722 8.328 8.502 0 0 0 0 0 0 0 0 * * * 2 * * * * 5 * * * * .17 * * * * 62 * * 75 * * * * * * * 10.43 10.43 * * * 14 * * * * 269 * * * * 95 * * * * 0.0 * 15.5 0 0 0 0 * * * n.32 * * * * 11.32 * * * * 11.33 * * * * 11.33 * DRILLING FLUIDS DATA MANAGEMENT SYSTEM 3 CASING SHOE ECD ~~w ECD+Cuttings Ib/gal TOTAL DEPTH PRESSURES , ECD Ib/gal i ECD+Cuttings Ib/gal 1M-I L.L.G: 021223012 10.44 10.44 /""---., ~ ~ Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Field/Area: NINILCHIK Description: Location: Daily Discussion M-I Well: 021223012 2/16/2002 I TD = 105 ft MATERIAL COST = $994.65 ¡Day 0 2-ENGINEERS STARTING 2-14-02 (PRE-SPUD MEETING) RIG UP TO SPUD. RIG UP TO SPUD. 2/17/2002 I TD = 435 ft MATERIAL COST = $543.50 I Day 1 DRLG W/GEL-GELEX SPUD MUD. SPUD 1800 HRS ON 2-17-02. 2/18/2002 i TD= 1800 ft I Day 2 MATERIAL COST = $1069.50 DRLG TO 1800'. PUMP 50 bbl ill-VIS SWEEP& CBU. SHORT TRIP OK WITH NO FILL. PUMP ANOTHER 50 bbl HI-VIS SWEEP & CBU. POOH FOR LOGGING. DRLG TO 1800'. PUMP 50 bbl HI-VIS SWEEP. SHORT TRIP TO COLLARS. TRIP OK & NO FILL. PUMP 50 bbl HI-VIS SWEEP, CBU & POOH 2/19/2002 I TD= 1800 ft I Day 3 MATERIALS = $799.00 RUN 9 5/8" 47 LB/FT CSG TO 1800', REDUCE YP ON MUD & CEMENT. RUN 9 5/8" 47 LB/FT CSG TO 1800'. REDUCE yP ON MUD & CEMENTED CSG. 2/20/2002 I TD= 1800 ft I Day 4 NO MATERIALS MIXED. WOe. ND DlVERTER. NU BOP'S. CLEAN PITS. PREP SYSTEM TO DRILL OUT. PREP TO MIX OBM. WOC. ND. NU BOP'S. 2/21/2002 I TD= 1800 ft I Day 5 TEST BOP'S. MIX 100 BBLS OF OBM. PU DP. TEST BOP'S. PUDP. .....--..., '.......... ~ Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Field/Area: NINILCHIK Description: Location: Daily Discussion M-I Well: 021223012 2/22/2002 I TD = 2400 ft i Day 6 WILL CARRY OBM MATERIAL MIXED UNTIL DISPLACEMENT. WBM MATERIAL USED = P U 4" DP. STAND BACK. MU BHA. RIH. TEST CSG. DRL OUT CMT & FLOAT EQUIPMENT. TEST FORMATION TO 12.5 PPG EQUIV.DRL AHEAD. . PU 4" DP TO BE ABLE TO DRILL TO 5000'. STAND BACK. MU BHA; RIH. TEST CSG. DRL CMT & FLOAT. TEST FORM TO 12.5PPG. DRLG. 2/23/2002 I TD= 3575 ft I Day 7 MATERIAL COST = SCREEN DOWN TO 175 MESH AND 140 MESH ON SHAKERS. RUN WATER AND CENTRIFUGE TO CONTROL MUD WEIGHT. DRL TO 2783'. SH TRIP TO SHOE. DRL AHEAD. 2/24/2002 I TD= 4900 ft I Day 8 MAKE PREPS FOR SWITCHING TO OBM. MATERIAL COST = $ DRL TO 3809'. SH TRIP TO 2000'. DRL AHEAD. RUN WATER AND SOLIDS CONTROL AS DIRECTED. DRL TO 3809'. SH TRIP TO 2000'. DRL AHEAD. MAKE PREPARATIONS FOR SWITCHING TO OBM. 2/25/2002 I TD = 5400 ft I Day 9 EVERYBODY PITCHED IN TO WORK THROUGH THE OBM/WBM INTERFACE TO HELP THE MUD GO THROUGH THE TROUGH WHICH IS HORIZONAL DOWN TO PIT #4. MATERIAL COST FOR OBM TO DATE = $ DRL TO 5068'. PUMP/ROTATE UP TO 3800'. PUMP OUT TO SHOE. LOOKED GOOD. PREP TO DISP WHILE TRIPPING. GO TO BOTTOM. DISP TO OBM. DRL AHEAD AFTER CLEANING WATER MUD PITS. DRL TO 5068'. PUMP/ROTATE OUT TO 3800'. PUMP OUT TO SHOE; LOOKED GOOD. PREP TO DISP. DISP TO OBM. DRL TO 5400 AT 2400. 2/26/2002 I TD = 6257 ft I Day 10 RETORT CUTTINGS SAMPLE: 20 OIL, 15 WATER AND 65 SOLIDS. DRL TO 6137'. SH TRIP TO PU DP. DRL AHEAD. DRL TO 6137. SH TRIP TO PU DP. 2/2712002 I TD = 6910 ft MATERIAL COST = $1133.60 I Day 11 RETORT CUTTINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS. MAPCO 200 ON LOCATION: 31Q.6 bbls DRLG TO 6628'. POOH TO 6415' & WORK ON TOP DRIVE. RIH & DRILLED AHEAD. 2 ,~. ,.-.. , ~ Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Field/Area: NINILCHIK Description: Location: Daily Discussion M-I Well: 021223012 2/28/2002 ! TD= 7257 ft I Day 12 MATERIAL USED = $9451.00 RETORT CUITINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS. MAPCO ON LOCATION: 23IBBLS DRLG TO CORE PT @ 7257'. CBU. PUMP DRY JOB. POOH. DRLG TO CORE PT @ 7257'. CBD. PUMP DRY JOB. POOH. 3/1/2002 i TD = 7341 ft MATERIAL USED: $5002.18 I Day 13 RETORT CUITINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS MAPCO ON LOCATION: 164 bbls CORING RIH w CORE #1. TAG FILL @ 7235'. WASH FILL 7235'-7257' (hole trying to pack off). CORING 7257' - 7341.5' 3/2/2002 I TD= 7419 ft I Day 14 MATERIAL USED = $3035.86 RETORT CUITINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS. MAPCO ON LOCATION: 337 bbls LID CORE BBL. RIH WITH OUT MUD MOTOR. CBU. PUMP DRY JOB & POOH w.CORE BBL. CLEAN RIG FLOOR. LAY DN MUD MOTOR. PU ROTARY ASSM. 3/3/2002 I TD= 7758 ft I Day 15 MATERIAL USED = $3518.94 RETORT CUITINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS. MAPCO ON LOCATION: 286 bbl DRLG. DRLG. 3/4/2002 I TD = 7985 ft MATERIAL USED = $6830.74 I Day 16 RETORT CUITINGS SAMPLE: 20 OIL, 15 WATER & 65 SOLIDS. MAPCO ON LOCATION: 210 bbls DRLG. REPAIR TOP DRIVE. DRLG. DRLG TO 7808'. REPAIR TOP DRIVE. POOH TO 7110' (PULLED 40K OVER @ 7606-7518' & 7469'.) TOP DRV. RIH OK. DRLG. TOP DRV. 3 ,~ ,-.... , ~ Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK Field/Area: NINILCHIK Description: Location: Daily Discussion M-I Well: 021223012 3/5/2002 I TD= 8000 ft ! Day 17 I MATERIAL USED = $1812.40 MAPCO DELIVERED 3-5-02 = 8000 GALLONS MAPCO ON LOCATION = 402bbls TO @ 8000'. SHORT TRIP OK. POOH TO LOG. LOGGING OK. DRLG TO 8000' TO. SHORT TRIP TO 7110' OK. RIH & POOH TO LOG. LOGGER'S DEPTH - 8000'. LOGGING OK. 3/6/2002 I TD = 8000 ft MATERIAL USED = $2397.36 I Day 18 MAPCO BASE OIL ON LOCATION = 398 bbls. LOGGING. RUN 7" CSG. LOGGING WITH C-SA T SCHLUMBERGER TOOL. LD BHA. CHANGE TO 7" RAMS & TEST. RUN 7" CSG. 3/7/2002 I TD= 8000 ft I Day 19 Material used= Mapco Base 011 On Location=398 BBLS run 7" and cement running 7" casing and cementing 3/8/2002 I TD= 8000 ft I Day 20 MATERIAL USED = $1186.92 MAPCO BASE OIL ON LOCATION = 490 BBLS MAPCO BASE OIL DELIVERED 3-8-02 = 4200 GALLONS FINISH 2nd STAGE CEMENT JOB. RIH TO 5033'. DRLG. FINISH 2nd STAGE CEMENT JOB. TEST PACK OFF & NECK SEALS. RIH 5033' & TEST CSG TO 3000psi. DRLG DV TOOL. 3/9/2002 I TD= 3707 ft I Day 21 MATERIAL USED = $ 25584.72 MAPCO BASE OIL ON LOCATION = 102 bbls DISPLACE HOLE WI BASE OIL. REDUCE OBM MUD WT W/ CENTRIFUGE. DISPLACE OBM WITH BASE OIL. POOH WI 4" DP. RIH WI 3 1/2" TUBING & SET PACKER @ 3707. 3/10/2002 I TD = 7920 ft MATERIAL USED = $791.28 I Day 22 MAPCO ON LOCATION = 90 bbls 2nd MUD ENGINEER RELEASED 3-10-02 CLEAN MUD PITS. LAY DOWN 4". NIPPLE DOWN. TEST BOP's. CLEAN MUD PITS. 4 ~ 3/11/2002 I TD = 7920 ft MATERIAL USED = $5282.15 MAPCO 200 ON LOCA nON = 70 BBLS ENGINEER RELEASED 3-11-02 CLEAN PITS & RIG DOWN. CLEAN PITS. RIG DOWN. r-"', Operator: UNOCAL Well Name: PEARL 1 Contractor: H & RlKUUKPIK I Day 23 ,~ Field/Area: NINILCHIK Description: Location: 5 Daily Discussion M-I Well: 021223012 UNOCAL8 PEARL No.1 Kenai Peninsula, Alaska Depth vs. Time Summary ¿ 1,000 \ 2,000 3,000 4,000 5,000 Z' ~ ~ :;; 6,000 .... c. ~ ~ 7,000 8,000 9,000 :- 0,000 _1,000 :_2,000 0 35 , ¿ 10 15 20 5 25 30 Time (Days) REVISED PEARL # 1 AFE 40 - PROPOSED PEARL # 1 DA YS VS -) DEPTH - ACTUAL PEARL # - 1 DAYS VS DEPTH FROM START ) 45 50 55 60 6/12/2002/10:39 AM SECURrIY DBS REPRESENTATIVE PHONE UNOCAl all & GAS BIT ¡GerOld Atol STOCK POINT AREA CODE PAGE ---1..- RECORD Anchorap:e OF 1 OPERATOR OPERATORS REPRESENTATIVE ~"UU UAI>. DRILL PIPE OD WT TJ SOURCE: NUMBER Unocal Fahrlender ¡Benson 2117/2002 CONTRACTOR CONTRACTORS REPRESENTATIVE UNDERSURFACE OD WT TJ H&R RIG NAME or NO. DlRECJ10NS TO RIG UNDER Ii'lŒRMEDIATE DRILL COLLARS OD ID LEN H.W. OD WT LEN H&R #9 Turn left at Deep Creek Realty, go 114 mile to rig turn in. WELL NAME or NO. UNDER Ii'lŒRMEDIATE OD ID LEN OD wr LEN PEARL # 1 SECIlON ITOWNSHIP RANGE FIELD BLOCK TO DATE #, PUMP MAKE MODEL LINER Ninilchik 3/4/2002 coumY STATE COUNTRY DAYS TOTAL HOURS # 2 PUMP MAKE MODEL LINER Kenai Pen.¡Cook Inlet Alaska USA 22 RUN BUYEF BIT BIT BIT IADC RR. lIT SERIAL 1VD JET MD PUMP FLOW MUD VER CUTIYNG STRuCTURE DATE # O/C SIZE MFR TIl'E CODE RB NUMBER OlJl' SIZE OlJl' FOOTAGE HOURS ROP WEIGHT RPM R.M.T PRESS GPM WT. DEV IDS OCS DC LOC B/S G ODC RP RUN 1 12 1/4 HTC MXCI 117 5002174 3-18.15 1800 1688 18.50 91.20 15-30 150 T 2200 793 9.3 .5 1 1 NO A E I TO I8-Feb 2 8 1/2 HTC OP0622 1905644 7-11's 7257 5457 85.50 63.80 8/15 150 M 3300 400 10.2 1.5 0 NO I I 0 A X NO CP 28-Feb ) / 3 8-15/16 SEC CO93 4980986 7-11's 7342 85 12.50 6.80 2-30 75-80 r 1800 267 10.2 1.5 I-Mar 4RR 81/2 HTC OP0622 1905644 7-11's 8000 658 42.50 15.50 5/25 150 R 2950 401 10.1 1.5 1 2 wr G X I NO TO 4-Mar 0.00 ) 9.625 Surface Cog Tally ~ ~ Tally Tubular Information: Casing Size: 9 5/8" 47# L-80 Butt w/ seal rings AFE Number: 153059 Well: Pearl # 1 Start Date: 2/19/02 Field: Nlnilchlk Start TIme: Platform: Date Landed: 2/20/02 Foreman: Jim Benson I BOb Wadley Time Landed: Rig: H&R Rig 9 Up-Weight: 98,000 Ibs Mud Weight (PPG): 9.3 Slack-off: 90,000 Ibs Mud Type: Spud Mud Weight set on SlIps/HGR: 90,000 Ibs Wellhead Make: Cameron 13 5/8" 3M Current Rig KB Elevation: 16.60 G.L. Original Rig KB Elevation: New well Joint Run Description ID" DO" LENGTI TOTAL TOP BTM. I BBLS Num Num (Iu~ COUPLING (It) LENGTH (It) (It) CAPACITY Rat Hole 8.79 8.79 1,791.21 1,800.00 Float Shoe Bakor Locked 8.681 10.625 1.70 1.69 1,789.51 1,791.21 1 1 9 5/8" 47# L-80 Butt Cog Baker Locked 8.681 10.625 41.33 43.02 1,748.18 1,789.51 2 2 9 5/8" 47# L-BO Butt Cog Baker Locked 8.681 10.625 42.18 85.20 1,706.00 1,748.18 Float Collar Baker Locked 8.681 10.625 1.55 86.75 1,704.45 1,706.00 3 3 9 5/8" 47# L-80 Butt Cog Baker Locked 8.681 10.625 41.40 128.15 1,663.05 1,704.45 3.03 4 4 95/8" 47# L-60 Buttress Casing 8.681 10.625 42.10 170.25 1,620.95 1,663.05 6.11 5 5 95/8" 47# L-BO Buttress Casing 8.681 10.625 42.09 212.34 1,578.86 1,620.95 9.19 6 6 95/8" 47# L-80 Buttress Casing 8.681 10.625 46.75 259.09 1,532.11 1,578.86 12.62 7 7 95/8" 47# L-BO Buttress Casing 8.681 10.625 47.25 306.34 1.484.86 1,532.11 16.07 8 8 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 46.80 353.14 1,438.06 1,484.86 19.50 9 9 95/8" 47# L-80 Buttress Casing 8.681 10.625 43.93 397.07 1,394.13 1,438.06 22.72 10 10 95/8" 47# L-BO Buttress Casing 8.681 10.625 44.86 441.93 1,349.27 1,394.13 26.00 11 11 95/8" 47# L-80 Buttress Casing 8.681 10.625 44.61 486.54 1,304.66 1,349.27 29.26 12 12 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 45.88 532.42 1,258.78 1,304.66 32.62 13 13 95/8" 47# L-80 Buttress Casing 8.681 10.625 46.22 578.64 1,212.56 1,258.78 36.01 14 14 95/8" 47# L-BO Buttress Casing 8.681 10.625 45.78 624.42 1,166.78 1,212.56 39.36 15 15 95/8" 47# Lo80 Buttress Casing 8.681 10.625 37.50 861.92 1,129.28 1,166.78 42.10 16 16 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 47.18 709.10 1,082.10 1,129.28 45.56 17 17 95/8" 47# L-BO Buttress Casing 8.681 10.625 42.10 751.20 1,040.00 1,082.10 48.64 18 18 9 5/8" 47# L-80 Buttress Casing 8.681 10.625 47.04 798.24 992.96 1,040.00 52.08 19 19 95/8" 47# L-BO Buttress Casing 8.681 10.625 47.05 845.29 945.91 992.96 55.53 20 20 9 5/8" 47# L-80 Buttress Casing 8.681 10.625 46.65 891.94 899.26 945.91 58.94 21 21 95/8" 47# LoBO Buttress Casing 8.681 10.625 46.61 938.55 852.65 899.26 62.35 22 22 9 5/8" 47# L-80 Buttress Casing 8.681 10.625 43.75 982.30 808.90 852.65 65.55 23 23 95/8" 47# L-BO Buttress Casing 8.681 10.625 37.73 1020.03 771.17 808.90 68.32 24 24 9 5/8" 47# L-80 Buttress Casing 8.681 10.625 46.41 1068.44 724.76 771.17 71.71 25 25 9 5/6" 47# L-BO Buttress Casing 8.681 10.625 47.18 1113.62 677.58 724.76 75.17 26 26 95/8" 47# L-BO Buttress Casing 8.681 10.625 39.50 1153.12 638.08 677.58 78.06 27 27 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 47.14 1200.26 590.94 638.08 81.51 28 28 Ii 5/8" 47# L-80 Buttress Casing 8.681 10.625 44.37 1244.63 546.57 590.94 84.76 29 29 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 46.64 1291.27 499.93 546.57 88.17 30 30 95/8" 47# L-80 Buttress Casing 8.681 10.625 46.43 1337.70 453.50 499.93 91.57 31 31 9 5/8" 47# LoBO Buttress Casing 8.681 10.625 42.01 1379.71 411.49 453.50 94.64 32 32 95/8" 47# L-BO Buttress Casing 8.681 10.625 42.00 1421.71 369.49 411.49 97.72 33 33 9 5/8" 47# L-BO Buttress Cosing 8.681 10.625 42.00 1463.71 327.49 369.49 100.79 34 34 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 41.77 1505.48 285.72 327.49 103.85 35 35 95/8" 47# L-80 Buttress Casing 8.681 10.625 42.10 1547.58 243.62 285.72 106.93 36 36 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 40.78 1588.36 202.84 243.62 109.92 37 37 95/8" 47# L-80 Buttress Casing 8.681 10.625 41.38 1629.74 161.46 202.84 112.95 38 38 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 39.28 1669.02 122.18 161.46 115.82 39 39 95/8" 47# Lo80 Buttress Casing 8.681 10.625 41.97 1710.99 80.21 122.18 118.89 40 40 9 5/8" 47# L-BO Buttress Casing 8.681 10.625 41.07 1752.06 39.14 80.21 121.90 Cameron Fluted Hanger w / pup JI 17.83 1769.89 21.31 39.14 123.21 RKB 21.31 1791.20 0.00 21.31 124.77 1791.20 7.31'olslickup 57 Total JI Plus 4 Pup Jls 01 9 5/8" CS!I on Locallon Note: All connections in tho bottom 127' are Baker Locked. I I 50 Total lis a5/e" cog on Local",n. e lis a 5/S" cog LEFT ON RACK ( plus 4 pup lis) Psge1 011 ]6/12/2002-9:07 AM /~ ~ UNOCAL Tubular Information: Tubular Size Well: Field: Platform: Foreman: Rig: Mud Weight (PPG): Mud Type: Wellhead Make: Current Rig KB Elevation: Original Rig KB Elevation: Tubular Tally 3 1/2" Tubing Pearl #1 South Ninilchik AFE Num ber: Start Date: Start Time: Date Landed: Time Landed: Up-Weight: S la ck-off : Weight set on Slips/HGR: 153059 3/9/02 FahrlenderlStock H&R Rig 9 7.8 Base Oil Cameron Ibs Ibs Ibs 19.45 JT. Run Description ID" OD" LENGTH TOTAL TOP BTM. Num. Num. (in) (in) (ft) LENGTH (ft) (ft) Rat Hole 17.20 17.20 7,982.80 8,000.00 Halliburton Float Shoe 6.184 7.563 1.50 1.50 7,981.30 7,982.80 1 1 7" 29# L-80 TKC Plus Buttress 6.184 7.563 42.88 44.38 7,938.42 7,981.30 2 2 7" 29# L-80 TKC Plus Buttress 6.184 7.563 41.96 86.34 7,896.46 7,938.42 Halliburton Float Collar wi Baffle Plate 6.184 7.563 1.00 . 87.34 7,895.46 7,896.46 3 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.23 131.57 7,851.23 7,895.46 Halliburton Landing Collar 3.800 7.563 1.00 132.57 7,850.23 7,851.23 4 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.54 176.11 7,806.69 7,850.23 3 5 7" 29# L-80 TKC Plus Buttress 6.184 7.563 42.62 218.73 7,764.07 7,806.69 4 6 7" 29# L-80 TKC Plus Buttress 6.184 7.563 40.58 259.31 7,723.49 7,764.07 5 7 7" 29# L-80 TKC Plus Buttress 6.184 7.563 40.98 . 300.29 7,682.51 7,723.49 6 8 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.13. 344.42 7,638.38 7,682.51 7 9 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.19 388.61 7,594.19 7,638.38 8 10 7" 29# L-80 TKC Plus Buttress 6.184 7.563 40.01 428.62 7,554.18 7,594.19 9 11 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.39 472.01 7,510.79 7,554.18 10 12 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.23 516.24 7,466.56 7,510.79 11 13 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.13 559.37 7,423.43 7,466.56 12 14 7" 29# L-80 TKC Plus Buttress 6.184 7.563 38.22 597.59 7,385.21 7,423.43 13 15 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.13 641.72 7,341.08 7,385.21 14 16 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.66 685.38 7,297.42 7,341.08 15 17 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.28 729.66 7,253.14 7,297.42 16 18 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.73 773.39 7,209.41 7,253.14 17 19 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.10 817.49 7,165.31 7,209.41 18 20 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.19 861.68 7,121.12 7,165.31 19 21 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.19 905.87 7,076.93 7,121.12 20 22 7" 29# L-80 TKC Plus Buttress 6.184 7.563 47.45 953.32 7,029.48 7,076.93 A RA Tag Pup Jt. - 7" 29# L-80 TKC Plus Buttress 6.184 7.563 19.62 972.94 7,009.86 7,029.48 21 23 7" 29# L-80 TKC Plus Buttress 6.184 7.563 39.07 1,012.01 6,970.79 7,009.86 22 24 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.95 1,055.96 6,926.84 6,970.79 23 25 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.74 1,099.70 6,883.10 6,926.84 24 26 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.20 1,143.90 6,838.90 6,883.1 0 25 27 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.39 1,187.29 6,795.51 6,838.90 26 28 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.94 1,231.23 6,751.57 6,795.51 27 29 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.00 1,275.23 6,707.57 6,751.57 28 30 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.01 1,319.24 6,663.56 6,707.57 29 31 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.82 1,363.06 6,619.74 6,663.56 30 32 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.26 1,406.32 6,576.48 6,619.74 31 33 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.80 1,450.12 6,532.68 6,576.48 32 34 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.18 1,494.30 6,488.50 6,532.68 33 35 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.03 1,538.33 6,444.47 6,488.50 7 Casing Tally - Final Page 1 of 4 ]6/12/2002--9:08 AM I~ ~ JT. Run Descripth".. ID" OD" LENGTH .JTAL TOP BTM. Num. Num. (in) (in) (ft) LENGTH (ft) (ft) 34 36 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.22 1,582.55 6,400.25 6,444.47 35 37 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.18 1,626.73 6,356.07 6,400.25 36 38 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.36 1,671.09 6,311.71 6,356.07 37 39 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.90 1,714.99 6,267.81 6,311.71 38 40 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.87 1,758.86 6,223.94 6,267.81 39 41 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.00 1,802.86 6,179.94 6,223.94 40 42 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.99 1,846.85 6,135.95 6,179.94 41 43 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.34 1,891.19 6,091.61 6,135.95 42 44 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.12 1,935.31 6,047.49 6,091.61 43 45 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.43 1,979.74 6,003.06 6,047.49 B RA Tag Pup Jt. - 7" 29# L-80 TKC Plus Buttress 6.184 7.563 19.63 1,999.37 5,983.43 6,003.06 44 46 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.87 2,043.24 5,939.56 5,983.43 45 47 7" 29# L-80 TKC Plus Buttress 6.184 7.563 36.36 2,079.60 5,903.20 5,939.56 46 4B 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.22 2,123.82 5,858.98 5,903.20 47 49 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.36 2,168.18 5,814.62 5,858.98 48 50 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.20 2,212.38 5,770.42 5,814.62 49 51 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.99 2,256.37 5,726.43 5,770.42 50 52 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.82 2,300.19 5,682.61 5,726.43 51 53 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.00 2,344.19 5,638.61 5,682.61 52 54 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.40 2,388.59 5,594.21 5,638.61 53 55 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.66 2,432.25 5,550.55 5,594.21 54 56 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.44 2,476.69 5,506.11 5,550.55 55 57 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.03 2,520.72 5,462.08 5,506.11 56 58 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.30 2,565.02 5,417.78 5,462.08 57 59 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.08 2,609.10 5,373.70 5,417.78 58 60 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.35 2,653.45 5,329.35 5,373.70 59 61 7" 29# L-80 TKC Plus Buttress 6.184 7.563 46.15 2,699.60 5,283.20 5,329.35 60 62 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.20 2,743.BO 5,239.00 5,283.20 61 63 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.15 2,787.95 5,194.85 5,239.00 62 64 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.35 2,832.30 5,150.50 5,194.85 63 65 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.50 2,876.80 5,106.00 5,150.50 Halliburton 'ES Cementer - Type H' 4.663 8.438 2.50 2,B79.30 5,103.50 5,106.00 64 66 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.83 2,923.13 5,059.67 5,103.50 65 67 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.10 2,967.23 5,015.57 5,059.67 66 68 7" 29# L-80 TKC Plus Buttress 6.184 7.563 39.50 3,006.73 4,976.07 5,015.57 C RA Tag Pup Jt. " 7" 29# L-80 TKC Plus Buttress 6.276 7.563 19.65 3,026.38 4,956.42 4,976.07 67 69 7" 29# L-BO TKC Plus Buttress 6.184 7.563 43.45 3,069.83 4,912.97 4,956.42 68 70 7" 29# L-BO TKC Plus Buttress 6.184 7.563 43.46 3,113.29 4,869.51 4,912.97 69 71 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.48 3,157.77 4,825.03 4,869.51 70 72 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.04 3,201.81 4,780.99 4,825.03 71 73 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.43 3,246.24 4,736.56 4,780.99 72 74 7" 29# L-BO TKC Plus Buttress 6.184 7.563 35.24 3,2B1.48 4,701.32 4,736.56 73 75 7" 29# L-80 TKC Plus Buttress 6.184 7.563 44.12 3,325.60 4,657.20 4,701.32 74 76 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.10 3,369.70 4,613.10 4,657.20 75 77 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.35 3,413.05 4,569.75 4,613.10 76 78 7" 29# L-80 TKC Plus Buttress 6.184 7.563 43.56 3,456.61 4,526.19 4,569.75 77 79 7" 29# L-80 TKC Plus Buttress 6.184 7.563 36.69 3,493.30 4,489.50 4,526.19 78 80 7" 29# L-BO TKC Plus Buttress 6.184 7.563 44.19 3,537.49 4,445.31 4,489.50 79 B1 7" 26# L-BO Buttress 6.276 7.563 41.59 3,579.08 4,403.72 4,445.31 80 82 7" 26# L-80 Buttress 6.276 7.563 40.67 3,619.75 4,363.05 4,403.72 81 83 7" 26# L-BO Buttress 6.276 7.563 41.49 3,661.24 4,321.56 4,363.05 82 84 7" 26# L-80 Buttress 6.276 7.563 41.56 3,702.BO 4,280.00 4,321.56 83 85 7" 26# L-80 Buttress 6.276 7.563 41.05 3,743.85 4,238.95 4,280.00 84 B6 7" 26# L-80 Buttress 6.276 7.563 41.57 3,785.42 4,197.38 4,238.95 85 87 7" 26# L-80 Buttress 6.276 7.563 41.55 3,B26.97 4,155.83 4,197.38 86 88 7" 26# L-80 Buttress 6.276 7.563 40.56 3,867.53 4,115.27 4,155.83 87 89 7" 26# L-80 Buttress 6.276 7.563 40.73 3,908.26 4,074.54 4,115.27 88 90 7" 26# L-80 Buttress 6.276 7.563 41.56 3,949.82 4,032.98 4,074.54 89 91 7" 26# L-80 Buttress 6.276 7.563 41.55 3,991.37 3,991.43 4,032.98 90 92 7" 26# L-80 Buttress 6.276 7.563 41.34 4,032.71 3,950.09 3,991.43 91 93 7" 26# L-BO Buttress 6.276 7.563 41.10 4,073.81 3,908.99 3,950.09 7 Casing Tally - Final Page2of4 ]6/12/2002-9:08 AM ,-.., ,-.., JT. Ron DescriptIo" ID" OD" LENGTH . JT AL TOP BTM. Nom. Nom. (in) (in) (ft) LENGTH (ft) (ft) 92 94 7" 26# L-80 Buttress 6.276 7.563 40.80 4,114.61 3,868.19 3,908.99 93 95 7" 26# L-80 Buttress 6.276 7.563 41.56 4,156.17 3,826.63 3,868.19 94 96 7" 26# L-80 Buttress 6.276 7.563 41.55 4,197.72 3,785.08 3,826.63 95 97 7" 26# L-80 Buttress 6.276 7.563 41.53 4,239.25 3,743.55 3,785.08 96 98 7" 26# L-80 Buttress 6.276 7.563 41.35 4,280.60 3,702.20 3,743.55 97 99 7" 26# L-80 Buttress 6.276 7.563 40.33 4,320.93 3,661.87 3,702.20 98 100 7" 26# L-80 Buttress 6.276 7.563 40.69 4,361.62 3,621.18 3,661.87 99 101 7" 26# L-80 Buttress 6.276 7.563 41.57 4,403.19 3,579.61 3,621.18 100 102 7" 26# L-80 Buttress 6.276 7.563 41.56 4,444.75 3,538.05 3,579.61 101 103 7" 26# L-80 Buttress 6.276 7.563 41.54 4,486.29 3,496.51 3,538.05 102 104 7" 26# L-80 Buttress 6.276 7.563 41.45 4,527.74 3,455.06 3,496.51 103 105 7" 26# L-80 Buttress 6.276 7.563 41.55 4,569.29 3,413.51 3,455.06 104 106 7" 26# L-80 Buttress 6.276 7.563 40.88 4,610.17 3,372.63 3,413.51 105 107 7" 26# L-80 Buttress 6.276 7.563 41.57 4,651.74 3,331.06 3,372.63 106 108 7" 26# L-80 Buttress 6.276 7.563 41.28 4,693.02 3,289.78 3,331.06 107 109 7" 26# L-80 Buttress 6.276 7.563 41.03 4,734.05 3,248.75 3,289.78 108 110 7" 26# L-80 Buttress 6.276 7.563 41.02 4,775.07 3,207.73 3,248.75 109 111 7" 26# L-80 Buttress 6.276 7.563 41.57 4,816.64 3,166.16 3,207.73 110 112 7" 26# L-80 Buttress 6.276 7.563 41.00 4,857.64 3,125.16 3,166.16 III 113 7" 26# L-80 Buttress 6.276 7.563 41.54 4,899.18 3,083.62 3,125.16 112 114 7" 26# L-80 Buttress 6.276 7.563 40.24 4,939.42 3,043.38 3,083.62 113 115 7" 26# L-80 Buttress 6.276 7.563 41.54 4,980.96 3,001.84 3,043.38 114 116 7" 26# L-80 Buttress 6.276 7.563 41.47 5,022.43 2,960.37 3,001.84 115 117 . 7" 26# L-80 Buttress 6.276 7.563 41.58 5,064.01 2,918.79 2,960.37 116 118 7" 26# L-80 Buttress 6.276 7.563 40.58 5,104.59 2,878.21 2,918.79 117 119 7" 26# L-80 Buttress 6.276 7.563 40.02 5,144.61 2,838.19 2,878.21 118 120 7" 26# L-80 Buttress 6.276 7.563 39.02 5,183.63 2,799.17 2,838.19 119 121 7" 26# L-80 Buttress 6.276 7.563 41.10 5,224.73 2,758.07 2,799.17 120 122 7" 26# L-80 Buttress 6.276 7.563 39.00 5,263.73 2,719.07 2,758.07 121 123 7" 26# L-80 Buttress 6.276 7.563 41.75 5,305.48 2,677.32 2,719.07 122 124 7" 26# L-80 Buttress 6.276 7.563 40.76 5,346.24 2,636.56 2,677.32 123 125 7" 26# L-80 Buttress 6.276 7.563 41.75 5,387.99 2,594.81 2,636.56 124 126 7" 26# L-80 Buttress 6.276 7.563 41.57 5,429.56 2,553.24 2,594.81 125 127 7" 26# L-80 Buttress 6.276 7.563 40.98 5,470.54 2,512.26 2,553.24 126 128 7" 26# L-80 Buttress 6.276 7.563 40.97 5,511.51 2,471.29 2,512.26 127 129 7" 26# L-80 Buttress 6.276 7.563 39.92 5,551.43 2,431.37 2,471.29 128 130 7" 26# L-80 Buttress 6.276 7.563 41.47 5,592.90 2,389.90 2,431.37 129 131 7" 26# L-80 Buttress 6.276 7.563 39.50 5,632.40 2,350.40 2,389.90 130 132 7" 26# L-80 Buttress 6.276 7.563 41.58 5,673.98 2,308.82 2,350.40 131 133 7" 26# L-80 Buttress 6.276 7.563 41.56 5,715.54 2,267.26 2,308.82 132 134 7" 26# L-80 Buttress 6.276 7.563 41.60 5,757.14 2,225.66 2,267.26 133 135 7" 26# L-80 Buttress 6.276 7.563 39.55 5,796.69 2,186.11 2,225.66 134 136 7" 26# L-80 Buttress 6.276 7.563 41.05 5,837.74 2,145.06 2,186.11 135 137 7" 26# L-80 Buttress 6.276 7.563 41.88 5,879.62 2,103.18 2,145.06 136 138 7" 26# L-80 Buttress 6.276 7.563 40.56 5,920.18 2,062.62 2,103.18 137 139 7" 26# L-80 Buttress 6.276 7.563 41.38 5,961.56 2,021.24 2,062.62 138 140 7" 26# L-80 Buttress 6.276 7.563 41.33 6,002.89 1,979.91 2,021.24 139 141 7" 26# L-80 Buttress 6.276 7.563 41.48 6,044.37 1,938.43 1,979.91 140 142 7" 26# L-80 Buttress 6.276 7.563 37.89 6,082.26 1,900.54 1,938.43 141 143 7" 26# L-80 Buttress 6.276 7.563 41.53 6,123.79 1,859.ü1 1,900.54 142 144 7" 26# L-80 Buttress 6.276 7.563 41.48 6,165.27 1,817.53 1,859.01 143 145 7" 26# L-80 Buttress 6.276 7.563 41.07 6,206.34 1,776.46 1,817.53 144 146 7" 26# L-80 Buttress 6.276 7.563 40.63 6,246.97 1,735.83 1,776.46 145 147 7" 26# L-80 Buttress 6.276 7.563 41.58 6,288.55 1,694.25 1,735.83 146 148 7" 26# L-80 Buttress 6.276 7.563 41.61 6,330.16 1,652.64 1,694.25 147 149 7" 26# L-BO Buttress 6.276 7.563 40.13 6,370.29 1,612.51 1,652.64 148 150 7" 26# L-80 Buttress 6.276 7.563 41.67 6,411.96 1,570.84 1,612.51 149 151 7" 26# L-80 Buttress 6.276 7.563 41.15 6,453.11 1,529.69 1,570.84 150 152 7" 26# L-80 Buttress 6.276 7.563 41.75 6,494.86 1,487.94 1,529.69 151 153 7" 26# L-80 Buttress 6.276 7.563 38.21 6,533.07 1,449.73 1,487.94 152 154 7" 26# L-80 Buttress 6.276 7.563 41.50 6,574.57 1,408.23 1,449.73 7 Casing Tally - Final Page30f4 ]6/12/2002--9:08 AM ---- ~ JT. Ron Descripn...-- ID" OD" LENGTH .JTAL TOP BTM. Nom. Nom. (in) (in) (ft) LENGTH (ft) (ft) 153 155 7" 26# L-80 Buttress 6.276 7.563 41.78 6,616.35 1,366.45 1,408.23 154 156 7" 26# L-80 Buttress 6.276 7.563 41.41 6,657.76 1,325.04 1,366.45 155 157 7" 26# L-80 Buttress 6.276 7.563 40.30 6,698.06 1,284.74 1,325.04 156 158 7" 26# L-80 Buttress 6.276 7.563 41.56 6,739.62 1,243.18 1,284.74 157 159 7" 26# L-80 Buttress 6.276 7.563 41.56 6,781.18 1,201.62 1,243.18 158 160 7" 26# L-80 Buttress 6.276 7.563 40.65 6,821.83 1,160.97 1,201.62 159 161 7" 26# L-80 Buttress 6.276 7.563 41.29 6,863.12 1,119.68 1,160.97 160 162 7" 26# L-80 Buttress 6.276 7.563 41.32 6,904.44 1,078.36 1,119.68 161 163 7" 26# L-80 Buttress 6.276 7.563 41.88 6,946.32 1,036.48 1,078.36 162 164 7" 26# L-80 Buttress 6.276 7.563 40.61 6,986.93 995.87 1,036.48 163 165 7" 26# L-80 Buttress 6.276 7.563 40.86 7,027.79 955.01 995.87 164 166 7" 26# L-80 Buttress 6.276 7.563 38.45 7,066.24 916.56 955.01 165 167 7" 26# L-80 Buttress 6.276 7.563 41.85 7,108.09 874.71 916.56 166 168 7" 26# L-80 Buttress 6.276 7.563 41.83 7,149.92 832.88 874.71 167 169 7" 26# L-80 Buttress 6.276 7.563 41.86 7,191.78 791.02 832.88 168 170 7" 26# L-80 Buttress 6.276 7.563 41.79 7,233.57 749.23 791.02 169 171 7" 26# L-80 Buttress 6.276 7.563 41.05 7,274.62 708.18 749.23 170 172 7" 26# L-80 Buttress 6.276 7.563 41.80 7,316.42 666.38 708.18 171 173 7" 26# L-80 Buttress 6.276 7.563 39.41 7,355.83 626.97 666.38 172 174 7" 26# L-80 Buttress 6.276 7.563 41.24 7,397.07 585.73 626.97 173 175 7" 26# L-80 Buttress 6.276 7.563 41.78 7,438.85 543.95 585.73 174 176 7" 26# L-80 Buttress 6.276 7.563 40.59 7,479.44 503.36 543.95 175 177 7" 26# L-80 Buttress 6.276 7.563 40.54 7,519.98 462.82 503.36 176 178 7" 26# L-80 Buttress 6.276 7.563 41.37 7,561.35 421.45 462.82 177 179 7" 26# L-80 Buttress 6.276 7.563 41.22 7,602.57 380.23 421.45 178 180 7" 26# L-80 Buttress 6.276 7.563 40.37 7,642.94 339.86 380.23 179 181 7" 26# L-80 Buttress 6.276 7.563 40.80 7,683.74 299.06 339.86 180 182 7" 26# L-80 Buttress 6.276 7.563 41.41 7,725.15 257.65 299.06 181 183 7" 26# L-80 Buttress 6.276 7.563 40.98 7,766.13 216.67 257.65 182 184 7" 26# L-80 Buttress 6.276 7.563 41.48 7,807.61 175.19 216.67 183 185 7" 26# L-80 Buttress 6.276 7.563 41.35 7,848.96 133.84 175.19 184 186 7" 26# L-80 Buttress 6.276 7.563 41.68 7,890.64 92.16 133.84 185 187 7" 26# L-80 Buttress 6.276 7.563 41.52 7,932.16 50.64 92.16 D Pup Jt. - 7" 29# L-80 TKC Plus Buttress 6.276 7.563 19.64 7,951.80 31.00 50.64 Hanger and Pup Joint 11.55 7,963.35 19.45 31.00 Landing Joint 27.50 7,990.85 (8.05) 19.45 8,008.05 7 Casing Tally - Final Page4of4 ]6/12/2002--9:08 AM /""'"'. ""--', Tubular Tally Tu Tubular Size: Well: Field: Platform: Foreman: Rig: H& R #9 Mud Weight (PPG): Mud Type: Wellhead Make: Current Rig KB Elevation: Original Rig KB Elevation: 3 1/2" Pearl #1 Deep Creek Prosp AFE Number: 153059 Start Date: 3/9/02 Start Time: 5:00PM Da te La nded: 3/10/02 Time Landed: 2:00 AM Up-Weight: 54,000- Slack-off: 54,000- Weight set on Slips/HGR: 54,000- -Includes weight of blocks. Ibs Ibs Ibs FahrlenderlStock H&R #9 9.0 M a pco 200 Cameron MB 17.4 Item Jt Description ID" OD" LENGTH TOTAL TOP BTM. (in) (in) (ft) LENGTH (ft) (ft) Total Depth 2.990 0.00 8,000.00 8,000.00 Rat Hole Below 7" Shoe 17.20 17.20 7,982.80 8,000.00 7" Shoe to Landing Collar (PBTD) 132.57 149.77 7,850.23 7,982.80 Rat Hole Below End ofTubing 4061.44 4,211.21 3,788.79 7,850.23 Wireline Re-Entry Guide with Shear Out Ball Seat 2.990 1.00 1.00 3,787.79 3,788.79 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.810 32.40 33.40 3,755.39 3,787.79 XN Nipple 2.81" by 2.666" No GD 2.990 1.18 34.58 3,754.21 3,755.39 2 3 1/2" 9.3 PPF L-80 SC Buttress Tubing . 2.990 32.28 66.86 3,721.93 3,754.21 3 1/2" 9.3 PPF L-80 SC Buttress Tubing Pup JI. 2.990 4.12 70.98 3,717.81 3,721.93 4 112" L T&C by 3 1/2" Buttress XO 2.990 0.67 71.65 3,717.14 3,717.81 Mill Out Extention 2.990 5.56 77.21 3,711.58 3,717.14 84 SAB 40 x 32 Baker Packer 2.990 4.92 82.13 3,706.66 3,711.58 Tubing Anchor 2.990 0.67 82.80 3,705.99 3,706.66 3 1/2" 9.3 PPF L-80 SC Buttress Tubing Pup JI. 2.990 6.19 88.99 3,699.80 3,705.99 3 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.87 120.86 3,667.93 3,699.80 4 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.77 152.63 3,636.16 3,667.93 5 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.46 184.09 3,604.70 3,636.16 6 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 7.990 31.47 215.56 3,573.23 3,604.70 7 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.37 247.93 3,540.86 3,573.23 8 3 1/2" 9.3 PPF L-80 SC Buttress Tubing '2.990 31.86 279.79 3,509.00 3,540.86 9 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.44 311.23 3,477.56 3,509.00 10 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.23 343.46 3,445.33 3,477.56 11 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.83 375.29 3,413.50 3,445.33 12 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.93 407.22 3,381.57 3,413.50 13 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.37 439.59 3,349.20 3,381.57 14 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.88 471.47 3,317.32 3,349.20 15 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 29.94 501.41 3,287.38 3,317.32 16 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.24 533.65 3,255.14 3,287.38 17 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.90 565.55 3,223.24 3,255.14 18 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 597.40 3,191.39 3,223.24 19 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.42 629.82 3,158.97 3,191.39 20 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.33 662.15 3,126.64 3,158.97 21 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.93 694.08 3,094.71 3,126.64 22 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.05 726.13 3,062.66 3,094.71 23 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.39 758.52 3,030.27 3,062.66 24 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.32 790.84 2,997.95 3,030.27 25 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.41 823.25 2,965.54 2,997.95 26 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.88 855.13 2,933.66 2,965.54 27 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.01 887.14 2,901.65 2,933.66 28 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.23 919.37 2,869.42 2,901.65 29 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.89 951.26 2,837.53 2,869.42 30 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 983.51 2,805.28 2,837.53 31 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.24 1,015.75 2,773.04 2,805.28 32 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.42 1,047.17 2,741.62 2,773.04 33 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 1,079.02 2,709.77 2,741.62 34 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.98 1,111.00 2,677.79 2,709.77 35 3112" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.29 1,142.29 2,646.50 2,677.79 36 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.38 1,173.67 2,615.12 2,646.50 37 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.90 1,205.57 2,583.22 2,615.12 38 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.79 1,237.36 2,551.43 2,583.22 39 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.18 1,269.54 2,519.25 2,551.43 40 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.88 1,301.42 2,487.37 2.519.25 PeaI11-3.5 Completion Tubing Page1Df3 ]6112/2002-9:08 AM "'-'" '----. Item Jt Description ID" OD" LENGTH TOTAL BTM. (in) (in) (ft) LENGTH (ft) (ft) 41 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.28 1,333.70 2,455.09 2,48737 42 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.23 1,365.93 2,422.86 2,455.09 43 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.08 1,397.01 2,391.78 2,422.86 44 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.95 1,427.96 2,360.83 2,391.78 45 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.29 1,460.25 2,328.54 2,360.83 46 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.24 1,492,49 2,296.30 2,328.54 47 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.36 1,523.85 2,264.94 2,296.30 48 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.80 1,554.65 2,234.14 2,264.94 49 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.76 1,586,41 2,202.38 2,234.14 50 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.27 1,617.68 2,171.11 2,202.38 51 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.87 1,649.55 2,139.24 2,171.11 52 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.33 1,680.88 2,107.91 2,139.24 53 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.94 1,712.82 2,075.97 2,107.91 54 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.89 1,744.71 2,044.08 2,075.97 55 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 1,776.56 2,012.23 2,044.08 56 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.85 1,809,41 1,979.38 2,012.23 3 1/2" 9.3 PPF L-80 SC Buttress Tubing Pup JI. 2.990 3,43 1,812.84 1,975.95 1,979.38 Injection Mandral with 1/4" SS Control Line tD Surface 2.990 5,437 7.57 1,820,41 1,968.38 1,975.95 3 1/2" 9.3 PPF L-80 SC Buttress Tubing Pup JI. 2.990 6.07 1,826,48 1,962.31 1,968.38 57 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.34 1,858.82 1,929.97 1,962.31 58 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 1,891.07 1,897.72 1,929.97 59 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.84 1,922.91 1,865.88 1,897.72 60 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 1,955.16 1,833.63 1,865.88 61 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.26 1,987,42 1,801.37 1,833.63 62 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.80 2,019.22 1,769.57 1,801.37 63 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.98 2,051.20 1,737.59 1,769.57 64 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 2,083.05 1,705.74 1,737.59 65 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.02 2,115.07 1,673.72 1,705.74 66 3 1/2" 9.3 PPF l-80 SC Buttress Tubing 2.990 31.91 2,146.98 1,641.81 1,673.72 67 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 2,178.83 1,609.96 1,641.81 68 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.13 2,210.96 1,577.83 1,609.96 69 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.92 2,242.88 1,545.91 1,577.83 70 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 2,274.73 1,514.06 1,545.91 71 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.93 2,305.66 1,483.13 1,514.06 72 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32,42 2,338.08 1,450.71 1,483.13 73 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.82 2,369.90 1,418.89 1,450.71 74 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.95 2,401.85 1,386.94 1,418.89 75 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.01 2,433.86 1,354.93 1,386.94 76 31/2" 9.3 PPFt-80 SC Buttress Tubing 2.990 31.20 2,465.06 1,323.73 1,354.93 77 3 1/2" 9.3 PPF J..-80 SC Buttress Tubing 2.990 32.25 2,497.31 1,291.48 1,323.73 78 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.85 2,529.16 1,259.63 1,291.48 79 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.77 2,560.93 1,227.86 1,259.63 80 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.75 2,592.68 1,196.11 1,227.86 81 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 2,624.93 1,163.86 1,196.11 82 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.81 2,656.74 1,132.05 1,163.86 83 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.21 2,688.95 1,099.84 1,132.05 84 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.75 2,720.70 1,068.09 1,099.84 85 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.90 2,752.60 1,036.19 1,068.09 86 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 2,784.85 1,003.94 1,036.19 87 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.44 2,816.29 972.50 1,003.94 88 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.28 2,846.57 942.22 972.50 89 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.28 2,877.85 910.94 942.22 90 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.82 2,909.67 879.12 910.94 91 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.73 2,941.40 847.39 879~12 92 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.33 2,972.73 816.06 847.39 93 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.13 3,003.86 784.93 816.06 94 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.38 3,035.24 753.55 784.93 95 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.98 3,066.22 722.57 753.55 96 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.27 3,098,49 690.30 722.57 97 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.75 3,130.24 658.55 690.30 98 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.96 3,162.20 626.59 658.55 99 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.49 3,193.69 595.10 626.59 100 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.50 3,225.19 563.60 595.10 101 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.01 3,257.20 531.59 563.60 102 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.82 3,289.02 499.77 531.59 103 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.89 3,320.91 467.88 499.77 104 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.25 3,353.16 435.63 467.88 105 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.86 3,385.02 403.77 435.63 106 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.61 3,416.63 372.16 403.77 107 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.50 3,448.13 340.66 372.16 108 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 30.65 3,478.78 310.01 340.66 109 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.23 3,511.01 277.78 310m 110 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.01 3,543.02 245.77 277,78 111 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.22 3,575.24 213.55 245.77 Pearl 1-3.5 CompletiDn Tubing Page 2 013 ]6/12/2002-9:08 AM _. ,-, Item Jt Description ID" OD" LENGTH TOTAL . BTM. (in) (in) (ft) LENGTH \ t) (ft) 112 3 1/2" 9,3 PPF L-80 SC Buttress Tubing 2,990 31.84 3,607,08 181.71 213.55 113 3 1/2" 9,3 PPF L-80 SC Buttress Tubing 2.990 32.54 3,639.62 149.17 181.71 114 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.11 3,671.73 117.06 149.17 115 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32,01 3,703.74 85.05 117.06 116 31/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 32.09 3,735.83 52,96 85.05 117 3 1/2" 9.3 PPF L-80 SC Buttress Tubing 2.990 31.79 3,767.62 21.17 52.96 3 1/2" 9.3 PPF L-80 SC Buttress Tubing Pup JI. 2,990 332 3,770,94 17.85 21.17 Hanger 0.48 3,771.42 17.37 17.85 RKB to Hanger Flange 17.37 3,788.79 0.00 17.37 Peart 1-3.5 CDmpletion Tubing Page30f3 ]6/12/2002-9:08 AM WELL PERMIT CHECKLIST COMPANY ~DC4. ( WELL NAME ø ¡-I #1 PROGRAM: exp v"/dev - redrll- serv - well bore seg _ann. disposal para req - FIELD & POOL /II/) INIT CLASS eX? I (64.6") GEOL AREA 87 n UNIT# /V"".4 ON/OFF SHORE () Þr ADMINISTRA TION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . .~N , 17 . ",/ 0 2. Lease number appropriate. " . . . . . . . . . . . . . . . . ,N ru 1<-4c.S,,:-) t{110Ct1.-L /¿4.;;.e.. ¡i/ /tJ 3C>3~ . L~,:,~;s /Úd-<. "4.¡-~"¿-.I r~ d; 3. Unique well ~ame and number... . . . . . . . . . . . . . . . ',- N *i,~ ~{"'Vt.~¿JÆ......ß~~"- <>.Surf6Lc:.£ ;¿;:;c-~-f ..::zZ::>.# /5"70il'ß3 .- 4. Well located In a defined pool.. . . . . . . . . . . . . . . . . Æ$y N ~/ø-r.q~ð ú.9-?/I- , - , .'\ 5. Well located proper distance from drilling unit boundary}'C. .. , -,'¡¡¿ "~~~.~-CR.~~ ;:-~:j;?,,(rGE:f,~ 2D M, C ß,o,5S( 0..)(2..1 ~.s 6. Welll?cated proper di~tan~ fro~ ~ther ':'Iells.. . . . . . . . . Y ~s r~ ;.;J[/( -~ f'Þ7-~ /QX!j "- ø; - ~ Iz,¡ -¿,À.a- ~ ¿:'. D. #" ~ - 7. Suffj~enta<?"eageavallabl~lndnlhngunlt............ ,yœ ~~~{¡~--l..<I _4~N-fAr ..L-y:c."/~he6.{ (.n~U~,~k-d,..".. /-/!;:OZ& 8. If deviated, IS wellbóre plat Included.. . . . . . . . . . . . .. /'Ill- Y N - v'e..II".fr ~ f () V (J /~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ~~ - - 10. Operator has appropriate bond in force. . . . . . . . . . . . . ~!5L .--7' ,,' - A" ~'~.. ;1, // / ;t' . /. / ' / ,/:1" :# ' ' 11. Pennit can be issued without conservation order. . . . . . . . " - I V--t5r, t<.x./( tA ¡ÇK y r /1 ¿¿/ .-<.-.2Cù -v?U- IYM' U (¿ - j,t1'Ü I I AP. DATE 12. Pennit ca~'be issued without administrativ~ approval.. . . . . '~u.J!u¿L' l1tud/ó ð.-' -/1--"....",... 2DD" ~ 'z.{'/;r, ,.)¡'i) ¡. :2$oz...13. Can penn' be ap,proved before 15-day walt. ," " " .. ' " - "' ~ (1<), Ai ~ -rs ,:;). . ~~~ - ~, L~. ~ -4;,I-iA~ 7 ~,- O'.ff:x.-f , ENGINEERING 14. Conductor s.tring provided. . . . . . . . . . . . . . . . . .. ,. ~ N tv<..// ~~ '/:/ ,h~1f:ø ~ ~~ ~ Aol- ~8u/" / 15. Surfacecasmgprotect~allknownUSDWs. . . . . . . . . . "1N ~& ö, ,¿A.~ '<4 ~~ ~-~.....s¿, _4-~ ," ,'<:.. 16. C MT VO, I adequate to <:arc:ulate on c:onductor & surf csg. . . . . ,N-I-k~,~~" 4' /".17 ÞleL/14 ~ ;0 ú.-:Jfi:.,. -:--- ~ S:ú-t'5 :><2.--1- a.<f /J'ðô 77/h.?l nl ( 17. CMT vol adequate totie-tn long string to surf csg. . . . . . . . N ~-rV ~ ¡>o~-h':......l' tt..s.J::>¿J :s.. .4D /, fLð'- óz . ' 18. CMT will cover all known productive horizons. . . . . '. . . .. ' N 19. Casing designs adequate forC, T, 8 & permafrost. . . . . . . ' N " . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N tH P- Tltj 9 . 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y. N NlA . 22. Adequate well bore separation proposed.. . . . . . . . . . . . N " " h ' -t 23. Ifdiverterrequired,doesitmeetregula,tions . . . . . . . . . . N i'l..i/ ÐiVe....-t-"'-r 0.- tt- 'Jet" iA..N2íl h.ût-R. WcJ..v.P,r of 1.oMc. "LS,D3SL'-)(I)@'j Y~\-<4 . 24. Drilling fluid program schematic & equip list adequate. . . . . N m 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 'Z' "j . : APP~i .J?A1J - 26. BOPE press rating appropriate; test to 3000 psig. N MÆ6P -:. ':>IP'T P k ~ ¡;Jql't '/L Via L. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N Jf.().?tv-. ( 28. Work will occur without operation shutdown. . . . . . . . . . . .t:l ~ KJj;- II ( 1,<; I-()") 29. Is presence of H28 gas probable.. . . . . . . . . . . . . . . . Y <!':!/ 1 GEOLOGY 30. Pennit can be issued wlo hydrogen sulfide measures. . . .. & N , / / '. /., /J ~, ' ~/ L , /,( ,4,1 31. Data presented on potential overpressure zones - . . . . . . ~N N~ a..-...-rzL';-¡f"':--r: ......., $£r t.v</ I cf??'? 0, / // 32. Seismic analysis ofshallow gas zones. . . . . . . . . . . . . ~ N 4~ ~hjf~f~ b~ .¡;/./s<-l- ~/ CC?1-f'76C,.,. nr:. A~ DAT.E- 33. Seabedconditionsurvey(lfoff-shore)............. x.JA,):~'" ~~ ~7(~(~ðQ<) AJ1<>¿J¿J~-----¡"'A':;"f..";"..5'L/in>/G- ~ AJ/ I, 2IN) L.- 34. Contact name/phone for weekly progress reports [exploratory onlYJ~ C?CF{ .¡. tt, .~ U : ANNULAR DISPOSAL35. With proper cementing records, this plan . ~ø(D$/<J z.c,. '3 -- Æ:, 77. ~ ' (A) will contain waste in a suitable receiving zone; . . . . . . . Y N. ,. - . APPR DATE (B) will not contaminate freshwater, or cause drilling waste. " Y N A1o Ck{ VllÁ-!~{ l/ M -=;fc;<;'cv ( tD \o.."",,~, to surface; , '( (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~~8 ~ _/ WM 8~s ffi t~I;I~?1Y) 'f"'I-'>? JMH JW.lt ,/ Comments/Instructions: IJ~/()2 c:\msoffice\wordian\diana\checldist (rev. 11/01/100) c 0 Z 0 -t :E ::0 ). / Z -t J: - en )- ::0 m > )