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Home My WebLink About201-155 Image hbject Well History File Cc"Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable Þ direct inspection of the file. Q 0 ,_ - J $ 5 Well History File Identifier R~CAN \¢' Color Items: D Greyscale Items: DIGITAL DATA ~scan Needed I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner Organizing (done) o Two-sided 1111111111111111111 o Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) ~s of various kinds: NOTES: Scanning Preparation BY: Helen CNtaria ) 7 D Other:: , I f) Date: g /0 00-/5/ V\1', I 1 / J ¡"I,.!J" ' Date:ß /0/ ()5 /s/ r r BY: Helen _~. Project Proofing BY: Hele~ x 30 = ~/O + = T:)TAL PAGES ,,':¡ / n (Count doe!;; not i~IUd, ,e, cover sheet) 1/'\/1 ~ Date: 8' 10 O,,-ç- /5/ t r I I Production Scanning Stage 1 Page Count from Scanned File: !(~ I J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO Helen ~ Date: q- "0 OS Is! WI P If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: /5/ 11I1111111111111111 1111111111111111111 I Date: /5/ Quality Checked III II 11111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • Marathon JNARaiNON Alaska Production LLC July 7, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Mar~LFion Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~ ~U~ ~ ?~1~11 Alaska dl~ ~ ~~ ~~bd. ~n~~=~~~,~~ .~nci~~r o~ Field: Ninilchik Unit Well: Falls Creek 1RD ~~~ ~il,~'~. F ~~~ Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for FC-1 RD well. This report covers the work performed to install a velocity string in FC-1 RD. The string was set at 7,350' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, r .,~Q~i,'~/~ Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~ ,1.~~~~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Install Velocity Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Dri I`Number: Name: Marathon Alaska Production LLC Development ~ Ex lorato ^ p ry^ 201-155 3. Address: PO BOX 1949 Stratigraphic ^ Service ^ 6. API Number: 133 10005 01 ~" 50 Kenai Alaska, 99611-1949 - - - 7. Property Designation (Lease Number): °~ 8. Well Name and Number: ~ ADL-00590 Falls Creek #1 RD 9. Field/Pool(s): Ninilchik Field/ yonek Pool ~h -~ ~ i ~ 11. Present Well Condition Summary: Total Depth measured 8,900' feet Plugs (measured) NA feet true vertical 8,322' feet Junk (measured) 8,725` feet Effective Depth measured 8,851' feet Packer (measured) NA feet true vertical 8,273' feet (true vertical) NA feet Casing Length Size MD TVD Burst Collapse Structural 28' 36" 28' 28' Conductor 248' 20" 248' 248' 2,110 psi 520 psi Surface 2,468' 13-3/8" 2,468' 2,440' 2,730 psi 2,260 psi Intermediate 3,150' 9-5/8" 3,150' 3,071' 5,750 psi 3,090 psi ~)~~fipQpsi Production 8,900' 4-1/2" 8,900' 8,322' 8,43~ ~~ Liner ~~((,,JJ Perforation depth: Measured depth: 5,706' - 8,750' ~ ~ ~: ~ ~ ~ p True Vertical depth: 5,153' - 8,172' ~~1~~k1(8 ~#) ~at ~8S C~#i~. r0#~iCI11SSI0fl a'ftf<~tt9l3~jP Tubing (size, grade, MD &TVD): Velocity String 1.75" HO-70 7,350' MD 6,772' TVD SSSV: NA NA MD NA TVD Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): A velocity string was installed to a setting depth of 7,350'MD. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1 0 - Subsequent to operation: 0 1,000 - 0 413 13. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-189 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ,~(nµ,~ Phone (907) 283-1371 Date July 7, 2010 V Form 10-404 Revised 7/2009 RBDMS !UL OS 211q~~ Submit Original Only ~~ ~~~ rations Summary Report by Job• ~nam-ilor ®OilCanpany Well Name: FALLS CREEK 1 Qtr/Qtr, Block, Sec, Town, Range Field Name License No. State/Province Country 6006001N012W01 NINILCHIK FALLS CREEK ALASKA USA Daily Operations Report Date: 6122/2010 Job Cate o WORKOVER 24 Hr Summary Rig up crane, install velocity string hanger, re-test tree, remove BPV, secure wellhead - -- ---- Start Time End Time Dur (hrsj Ops Code Activity Code Ops Status Trouble ' ~; Code Cpntment 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, obtain safe work permit, hold PJSM -topics discussed -PJSM -topics discussed -slips, trips, falls, hand safety, red lights for fire, blue lights for gas emission, sirens for audible, emergency vehicle, emergency phone numbes, muster area, buddy rule, three second rule. 08:00 08:30 0.50 RURD EQIP AF Rig up crane, remove welhouse. Pressure on wellhead - 600# 08:30 12:45 4.25 INSTAL SEOP AF Rig up Vetco lubricator to set BPV, set BPV, bleed off pressure, disconnect electrical, break tree between upper /master valves, install V string hanger, pressure test lower main valve to upper main valves across V string hanger, SSV and wing valve to 5000# -test successful. Bleed off pressure, rig up lubricator, pull BPV, rig down lubricator and crane 12:45 13:00 0.25 SECURE WELL AF Secure wellhead for evening, pressure test night cap - 600# on wellhead. Sign out, turn in work permit, leave location Report Date: 6/30/2010 Job Cate o WO RKOVER 24 Hr Summary MIRU BJ Coil. RU flowback tank, choke, gas buster, and iron. Perform successful BOP test, 250psi low - 4500psi high. Test witness waived by Jim Regg, AOGCC (6/29/10 @ 0900). RD BJ for night. - - -- - - '~, -- Ops Trouble Start Time i .End Time Dur (hrs) ' Ops Code Activity Code Status Code Comment - 07:30 08:00 0.50 SAFETY MTG AF PJSM w/ BJ Coil, ASRC, and operator. Discussed job operations, Held good communication, and emergency procedures. Obtained safe work permit. 08:00 11:00 3.00 RURD COIL AF MIRU BJ coil. Spot trucks and crane. RU flowback iron and equipment. RU BJ hardline to BOP and flow cross and stab on well. 11:00 12:00 1.00 TEST BOPE TA MSOT Prepare to pressure test, swab leaking. Call operator to shut well in. 12:00 13:00 1.00 TEST BOPE AF PT BOP as follows: Function test Blinds 250 low / 4500 high for 10 min Pipe rams 250 low / 4500 high for 10 min Shell test BOP and iron 4500 high for 10 min Good test. 13:00 13:30 0.50 RURD COIL AF RD BJ for night, secure well, sign out, turn in work permit, and leave location. Report Date: 7/1/2010 Job Cate o WORKOVER _ 24 Hr Summary RU BJ Coil and pigged 1.75" velocity string. Attach BHA and RIH to landing depth. Cut CT and MU coil hanger. Hang off CT string to set depth of 7,350' MD RKB. Successful test on seals to 5kpsi for 10 min. Pump off GS and BHA plug and flowback well. RD BJ for night. - - __ -- - Ops Trouble Start Time End Time Dur (hrs) ~~ Ops Code ~ Activity Code - Status Code Comment -- 07:30 08:00 0.50 SAFETY MTG AF Held PJSM w/ BJ, ASRC, and operator. Discussed communication, crane operations, and critical tasks. Obtained safe work permit. 08:00 08:45 0.75 PIG LINE AF Pump pig through CT. Pipe clean, pig recovered, and 23 bbls pumped. 08:45 11:15 2.50 PULD BHA AF Install external coil connector, pull test to 20klbs, good test. Nipple on to riser and stab on well. Purge string of fluid w/nitrogen. Remove riser from well and MU BHA as follows: 2.50" OD X 1.50" ID CT grapple connector, 2.50" OD X 1.50" ID X 10' long box x box straight bar, 1.91" OD X 1.25" PXN (1.135" no-go) pin x pin, 3.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re-entry guide with O-ring sealed aluminum pump-off plug. Stab riser on well, set depth counter, and open well. 11:15 13:00 1.75 RUNPUL COIL AF RIH w/ 1.75" CT to set depth of 7350' and 30' past to straighten coil. PUH to 7350' and measure wellhead distances. www.peloton.com Page 1/2 Report Printed: 7/2/2010 M ~ C~-ations Summary Report by Job• ,~,,,,ar„oN ®pjlryy Well Name: FALLS CREEK 1 Casing Flange Elevation (ft) Ground Elevation (ft) KB-Casing Flange Distance (ft) KB-Ground Distance (ft) Spud Date Rig Release Date __ _ - Ops Trouble Start Time ~ End Time Dur (hrs) Ops Code ~ Activity COde Status Code Comment 13:00 15:00 2.00 RUNPUL COIL AF Set slips and pipe rams, bleed off riser stack. Held JSA for critical operation. Walk injector up pipe, install c-plate and cut CT. Install GS assembly of reel side of coil. Install hanger assembly on wellhead side. Walk injector down coil and stab on well. Equalize slowly across hanger and pull test to 20klbs- good test. Release pipe/slip rams and RIH 12" above landing point. Run in landing screws. RIH 12" and land hanger, run in set screws. 1.75" velocity string landed @ 7350' MD RKB. 15:00 15:15 0.25 TEST TBG AF PT hanger seal to 5kpsi for 10 min. Good test. 15:15 16:15 1.00 PUMP N2 AF Pump nitrogen and release GS spear w/ 3000psi. Pump up v-string and pump off BHA plug @ 650psi. Bleed back well and riser. 16:15 17:15 1.00 RURD COIL AF LD riser and injector head. RD coil unit and equipment for night, secure well, sign out, and leave location. Daily Operations Report Date: 7/2/20 10 Job Cate o WORKOVER 24 Hr Summary RD BJ coil and flowback iron and equipment. Replace wellhouse and hand over to production. Ops ` , Trouble Start Time End Time .Dur (hrs) , Ops Code Attiv<ty Code Status Code Comment 08:00 08:30 0.50 SAFETY MTG AF _ _ Held PJSM w/ BJ, ASRC, and operator. Discussed emergency procedures, working at heights, and communication. Obtained safe work permit. 08:30 12:00 3.50 RURD COIL AF RD BJ coil iron and flowback iron. RD wellhead equipment and NU tree cap flange. Unstab pipe from injector, secure loads. Sign out, turn in safe work permit, and leave location. www.peloton.com Page 2/2 Report Printed: 7/2/2010 50-133-10005-01-00 ADL - 00590 276' (21' AGL) tude: 60 12' 15.857"N itg ude: 151 25' 46.322" W _ntrv Spud: 07/31/2001 =ntrv TD: 08/15/2001 Released: Falls Creek #1 RD Ninilchik Unit 1,898' FSL 8~ 2,885' FEL Sec. 6,T1 N, R12W, SM s ~.j 2 ~' `~•: 'i -,.; Baker Chemical Injection Nipple @ 1,950' MD (top) 5,930" OD/3.858" ID 8,430 psi burst17,500 psi collapse Top of Cement @ 2,650' MD gild 5.0 deg1100' from 3,094-3,924' MD ax angle at 45.5 deg at 3,924' MD 'op 2 deg/100' to 7,700' MD nal angle @ 0.5 deg to TD at 8,900' MD timuth: 270 deg. CIBP @ +/_ 3,151' (WLM) Cement Retainer @ 3,850' Cement Plug: 3,850' - 4,011' Cement Retainer @ 4,855' Cement Plug: 5,200' - 5,991' Casing Damage @ 5,315' Formation To as: Formation Death Beluga 2,077' MD 2,063' TVD Tyonek 5,513' MD 4,972' TVD Tyonek T3 7,595' MD 7,017' TVD TD 8,900' MD 8,322' TVD Baker Model D @ 7,545' Cement Plug: 7,562' - 7,641' 2-7/8", 6.5 ppf, N-80 8rd Float Collar @ 8,856' MD (Top) Float Shoe @ 8,900' MD (Bottom) Original Perfs: 3,900'-3,911' 5,290'-5,315' 5,442'-5,470' 7,562'-7,600' Sgz Holes: 3,884'-3,886' 5,275', 5,326', 5,419', 5,490' ~l~ M ~~u-n~oM Conductor 20" 97 ppf J-55 PE T~ Bottom MD 0' 248' TvD o' zas' 3.3/8" J-55 54.5 ppf STC TOE Bottom ID 0' 2,468' VD 0' 2,440' 8-5/8" hole Cmt w/ 1,660 sks of 12.5 ppg, Class G 9-5/8" N-80 40 ppf LTC T~ Bottom MD 0' 3,150' TVD 0' 3,071' 12-1/4" hole Cmt w/ 1884 sks of 12.5 ppg, Class G, Lead and 175 sks of 13.5 ppg, Class G, Tail Production Casing 4-1/2" L-80 12.6 ppf Mod Buttress T~ Bottom MD 0' 8,900' TVD 0' 8,322' 6.314" hole Cmt w/ 405 sks of 12.5 ppg Lead and 647 sks 15.7 ppg Tail, Class G Velocity String (installed 06/30/10) 1.75" 0.125" wall 1.50" ID T~ Bottom MD 0' 7350' TVD 0' 6772' 2.50" OD X 1.50" ID CT grapple connector, 2.50" OD X 1.50" ID X 10' long box x box straight bar, 1.91" OD X 1.25" PXN (1.135" no-go) pin x pin, 3.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re-entry guide 4 1/2" X Nipple (3.813" ID) @ 5,387' MD Existing Tyonek Perfs: MD TVD 5,706-5,736' 5,153'-5,182' Owen 3-3/8", 60 deg, 6spf 06107/2005 5,814-5,862' 5,256'-5,302' Owen 3-3/B", 60 deg, 6spf 06/0612005 5,875-5,885' 5,315'-5,324' Owen 3-3/8", 60 deg, 6spf 0610612005 6,405'-6,438' 5,832'-5,864' Owen 3-3/8", 60 deg, 6spf 11/23/04 7,335'-7,367' 6,757'-6,789' Owen 3-318", 60 deg, 6spf 7(7104. 7,403'-7,423' 6,825'-6,845' Owen 3-318", 60 deg, 6spf 716/04. 7,914'-7,934' 7,336'-7,356' Owen 2-318", 60 deg, 8spf (4SPF twice) 1/4104 8,714'-8,750' 8,136'-8,172' Schlumberger 2-7/8" PJ 2906 6spf 4108/2002 TD ~4~'•!~ PBTD 8,900' MD 8,851' MD 8,322' TVD 8,273' TVD line Fish: Consists of 1"fish neck 1-7/16" body on the wireline cable CCL, PX crossover sub, and 15' 3-3/8" OD (spent) perf gun. Well Name: Falls Creek #1 RD Lease: Ninilchik Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,706 - 8,750' (TVD): 5,153' - 8,172' Angle @ KOP and Depth: 3,094' MD Angle @Perfs: 45.5° Dated Completed: 419/2002 Completion Fluid: 6°/ KCL Revised by: James Ostroot Last Revison Date: 7/1/2010 • • ~~a~~ Oo ~ a~Gl~~{Q /~....~..~..~. Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production LLC P.O. Box 1949 ~l~~'~ ."~~`~ ` ~~ f ~J~~.i Kenai, AK 99611-1949 ~`~ Re: Ninilchik Field, Tyonek Pool, Falls Creek # 1 RD a,~ Sundry Number: 310-189 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel . Seamount, Jr. Chair DATED this ~ ~ day of June, 2010. Encl. • • Marathon h1ARATHON ®Alasl(a Production LLC June 14, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Ninilchik Unit Well: Falls Creek #1 RD Dear Mr. Aubert: Mar~n Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~ ~~ Submitted for your approval is the 10-403 Application for Sundry Approvals for FC-1 RD w II. ~/e propose to run a 1.75" velocity string, in FC-1 RD, to a target setting depth of 35,~ MD. The Cook Inlet region experiences large swings in the seasonal gas production demands. Marathon proposes this well-work activity to help mitigate the negative affects experienced by the infiltrating water during the low demand season. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-403 Application for Sundry Approvals Current Well Schematic Proposed Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS W- ~ !~ ,~ STATE OF ALASKA ~ ('~t ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALS ~n ner ~~ pan oa(I'1'2o10 ~~ d /~/~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair well ^ Change approved program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubin g ^ Specify: Time Extension ^ Operational shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter casing ^ Other: Install velocity string Q 2. Operator Name: Marathon Alaska Production LLC 4. Current Well Class: 5. Permit to Drill Number: ~ Development Q Exploratory ^ 201-155 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: ~ Kenai Alaska, 99611-1949 50-133-10005-01-59'r" ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. WeII Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No O Falls Creek #1 RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL-00590 Ninilchik Field/ Tyonek Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ~' 8,900' 8,322' 8,851' 8,273' NA 8,725' Casing Length Size MD TVD Burst Collapse Structural 2g' 36" 28' 28' Conductor 24g• 20" 248' 248' 2,170 psi 520 psi Surface 2,468' 13-3/8" 2,468' 2,440' 2,730 psi 2,260 psi Intermediate 3,150' 9-5/8" 3,150' 3,071' 5,750 psi 3,090 psi Production 8,900' 4-1/2" 8,900' 8,322' 8,430 psi 7,500 psi Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,706' - 8,750' ~ 5,153' - 8,172' NA NA NA Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): NA Packers: NA 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Weil Status after proposed work: Commencing Operations: June 29, 2010 Oil ^ Gas Q WDSPL ^ ^ Plugged 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J_Skiba Title Regulatory Compliance Representative Signature a 907 283.1371 Date ~ ~ ) June 14, 2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ) ~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ other: T'eS'~ ROPE {'O ~SC~O ~l e, . R~I V~D ~~ '~; ~ ~?_(110 Subsequent Form Required: (Q - G f O ~~ ~1..6.. ~,, ~, r , ~I ~~~~ ~~ f~~ -ClR11SS10 APPROVED BY Approved by: COMMISSI ,,:. . ,:,,: I ~ `_ ~~ T' 1 / ONER THE COMMISSION ' j ! Date: ~ Form 10-403 Revised 12/2009 ~ {~ RBDMS 1UN 18 ~~~ R I V I t ~ , ` ~ Submit in Duplicate "alf • • M MARATHON MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM Falls Creek #1 RD Ninilchik Unit Falls Creek Pad Coiled Tubing Velocity String Hangoff Procedure WBS # W0.10.22374.CAP.001 APPROVALS: aRance~ 8~t~oot 5/5/10 Program Writer .~V1;icP~e« /1Vlu~in 6J~/2U~U Mickey Mullin L. C. ~6ele, 6/14/10 Lyndon Ibele Latest Version Date: 6/1/10 Well Status: The well is producing 3.8 MMSCFD at 300 psi with around 1 BWPD. History: 03/20/10: PLT, flowing, FBHP 906 psi @ 147 deg. Fluid 7925'. 03/19/10: GR 2.87" tag 8724' (middle of lowest perfs) 06/08/05: Pert 5706-36 06/07/05: Perf 5875-85, 5814-62 11/23/04: Perf 6405-38 (15' gun fish in well) 07/08/04: Perf 7335-67 07/07/04: Perf 7403-23 06/25/04: GR 3.75 tag 8759 06/25/04: GR 3.80 tag nipple at 5389 01/03/04: Perf 7914-34 (production 6.2MM @ 1077psi to 10MM @ 1420psi) 01/02/04: Retrieve AD-2 Stop and memory gauges 12/28/03: Set F-stop and gauges at 8695 12/28/03: GR 3.60 tag 8741 12/28/03: GR 3.80 unable to pass 3.813 X nipple at 5387 04/08/02: Perf 8714-50 08/18/01: Drilled Well. Objectives: Install a 1.75" CT v-string at 7350'. This allows for +/-1.0 BCF ~ expected incremental recovery and reduced rates for summer curtailment (stable below 1 MM w/ VS), and ability to flow well past Q2 2012. Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -1- • • Resources: Coiled tubing set up with pump and N2 pump Approx 7500' of 1.75" CT Arctic Iron choke, gas buster, tank set up Manlift / 2 Light plants Vetco Crew for wellhead modifications/hangoff Procedure: A. Install Coiled Tubing Head Talk to construction and make arrangements to complete instrumentation, electrical, logic, and FCO to minimize shut-in time. Shut in well. Vetco to set 4" Cameron Type-H BPV. Close bottom master. Bleed off pressure and check for flow. Remove top master and install new Vetco 4-1/16 5M CT Head with 2-1/16" 5M side outlet. Install 2-1/16" gate valve and SSV to side outlet on coil tubing head. Reinstall and test (with diesel) top master and swab valve. Make final measurements to install flowline to CT Head outlet. Pull BPV. B. Flowline modifications for coil tubing string Hand over well to construction to modify flowline and install v-string flowline and choke. Velocity string flowline needs dedicated gas metering (IPR indicates appreciable rate gain for flowing up annulus). After complete, return well to production. C. MIRU MOC flowback equipment This includes open-top flowback tank, choke skid, gas buster, and flowback iron. Spot flowback tank close enough to run CT into tank for pigging. MIRU closed- top 500 bbl fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI. D. Hang Off 1.75" CT 1. MIRU BJ coiled tubing unit. Verify 24 hour notification has been made to AOGCC for BOP test. Rig up fluid and N2 pumps. RU pumping iron (BJ) and flow back iron (MOC). RU equalizing hose from BOP to top of lubricator. 2. Pig CT. Run end of CT with pig catcher made up into flowback tank. Pump 5 bbls water, cleaning pig, and coil displacement +10% behind pig. Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -2- • i 3. Ni le u BJ CT,vvellhead assembl WHA . Current WHA is 4-1/16" 5M swab/cap. Wh(A to include 4-1/16" - 5M X 4-1/16" - 10M DSA, 4-1/16" - 10M X 5' Flanged Riser, 4-1/16" -10M flow cross and 4-1/16" - 10M Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Have BJ coil tubing connector installed and pull test to 15,000 lbs. Nipple up injector to WHA. 4. Perform complete BOP test and complete AOGCC BOP test report (Correct form dated 01/25/2010). Pressure test pump iron (200 low/4500 high psi). Pump fluid to to CT. Pressure test CT, WHA and flow b iron to choke manifold (200/ 5 `psi). Pressure test BOP rams (200/4 OQ;'psi). Purge ~ pressure test tds w/ N2 to flowback tank and vent N2 sure to flowback tank. Note BOP test witness or waiver in WeIlView, including details. 5. MU CT BHA. Nipple injector off WHA. PU 10' of 4-1/16" CQ lubricator. MU velocity string BHA to end of CT. BHA to include: a. 2.50" OD X 1.50" ID CT grapple connector, b. 2.50" OD X 1.50" ID X 10' long box x box straight bar, c. 1.91" OD X 1.25" PXN (1.135" no-go) pin x pin, d. 2.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re-entry guide with 2.0 OD" x 2.50" OD O-ring sealed aluminum pump-off plug. Strap and record velocity string BHA dimensions and lengths. Include record in WeIlView and on updated WBD. 6. Nipple up infector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 7. RIH with coil tubing velocity string and BHA with well flowing to sales up annulus (running v-strings into shut in wells has been very unsuccessful). 8. Cut coil tubing. POH to span WHA for final landing depth, 7350' Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -3- r • 9. MU Vetco Coil Tubing Hanger and Weatherford Hydraulic Release GS Running Tool. (Only hand file outside of CT above BOP. NO HOT WORK PERMIT REQUIRED). GS running tool should be plugged to release on pressure, not rate. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger (4" Nom C/VV 3" Weatherford Fishneck with 2-3/8" 8rd Box and 2" BPV) to hanging coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Weatherford GS tool string assembly to coil on reel trailer. Dimple-on a 1-3/4" CT connector. Pull test CT connector (25,000 lbs.) using 1.125" 10SA box X 1- 1/2" MT pin crossover and 1-1/2" MT box pull plate. Tool string will consist of 1-3/4" slimline dimple-on, 1-3/4" DF check valve, 1.125' 10SA box X 1-1/2" MT pin X-over and a plugged 3" GS spear. PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger. 10. Latch GS spear to Vetco mandrel after PU injector. Remove polish rod clamp and C-plate from top of BOP. Accurately measure from hanger assembly to CT lock down screws. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 lbs. Slack off weight to CT string weight. Measure and mark the exact distance that the CT has to move down to align the hanger. Make all measurements on the gooseneck with all rollers locked. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 11. RIH and land Vetco CT hanger per Vetco procedures. (Stop hanger 1' high and run lower lockdown screws to their landing position. Lower hanger onto the lockdown screws and then lock upper screws. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten lock screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). 12. Release GS Running Tool. Start pumping 6% KCL water or N2 to pressure up CT to release GS spear. Set down weight and then pick GS off of hanger 13. RD and release CT. RD equipment, clean location, and turn in work permit. E. Pressure Up and Blow Pump-Off Plug Shut in sales and allow WHP pressure to build up to 1100 psi. Jumper gas from annulus to coil tubing until CT WHP is 1100 psi. While leaving CT shut in, open annulus to sales. The differential pressure between the coil tubing and annulus should blow off the pump out plug. If the situation dictates, pump off plug with N2. F. Flow Test Well to Sales Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -4- • . No more than a 60%drawdown with methane gas in wellbore is permitted for the lowest open interval. Obtain stabilized flow within the 60%drawdown limit. The unloading rate up 4-1/2" casing and 1.75" coil tubing in a vertical well is 4.0 MMCFPD and 638 MCFPD, respectively, at 800 psig FCP. Flow well to sales observing recommended drawdown rates. G. Complete Well Ops Transfer Sheet and distribute. WBD LINK FC O1RD PLT 03-19-10 F.zip Considerations, Instructions, and Planning: A pre-meeting with the construction group is required. Talk to construction and make arrangements to complete instrumentation, electrical, logic, and FCO to minimize shut-in time. V-string candidates don't normally like shut-ins, and having a "rush" job adds considerably to the cost of the tree work. A hot work permit is necessary for grinding the top of the CT above the BOP to allow installation of the dimple on connector when the v-string is pulled. This permit requires special approval and must be obtained before the job. When running the v-string, only allow hand filing of the outside of the CT above the tree to avoid the necessity of the hot work permit. Hand filing the outside is sufficient to install the external connector. Pigging the coil is a good practice generally and required if we are running used pipe from BJ. If you pig the CT stabbed onto the well you will fill the tree with rust and create problems. Make sure that everyone plans to pig directly into the tank to keep the debris away from the tree. The critical point in the job is spacing out to hang off the CT. If the space out and procedure is not correct the CT or hanger can easily be damaged causing significant extra time and money. Organize a job meeting before the injector is walked back down to the BOP to ensure everything is measured and correct. There are 2 kinds of CT hangers in the field. The new style hanger has seals that are energized by the lockdown screws. The old style hanger has o-rings and is a larger OD. If an old style hanger is pulled from the well it should be discarded and replaced with the new style. A third hanger is in final design as of Sept-09. This design has shear screws to stop from prematurely energizing the seal while running through the lubricator or tree. It is necessary to use straight bars to align the hanger and GS. Use a 6' straight bar between the CT connector and the hanger and above the GS spear use 2 large centralizers separated with a 2' - 3' straight bar. Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -5- • i If running a 4" hanger in 4-1/16" lubricator (or 3" in 3-1/8") it is necessary to install a pump in sub at the top of the lubricator and connect a hose from the top pump- in sub to the BOP to equalize around the hanger. Differential across the hanger can energize the seals and then they will be damaged running the hanger through the lubricator. Vetco is redesigning the 4" hanger to severely reduce this possibility (in final design stage in Sept09). It is safer to latch the hanger with the GS after the lubricator is reconnected to avoid walking the injector down the pipe. Either method works but with the straight bar below the hanger and the double centralizers above the GS it is easy to latch inside the lubricator. When running the 3" hanger latching the GS inside the lubricator is not an option unless you have 3-1/8" lubricator and an equalizing system. Coiled Tubing Velocity String Hangoff Procedure 6/1/10 -6- 4 I#: 50-133.10005-01-00 gyp. Des: ADL - 00590 I Elevation: 276' (21' AGL) 239,906 2,269,454 titude: 60 12' 15.857"N ngitude: 151 25' 46.322" W -Entry Spud: 0713112001 -Entry TD: 0 811 512 0 0 1 Top of Cement @ 2,650' MD CIBP @ +/- 3,151' (WLM) Cement Retainer @ 3,850' Cement Plug: 3,850' - 4,011' Cement Retainer @ 4,855' Cement Plug: 5,200' - 5,991' - Casing Damage @ 5,315' Baker Model D @ 7,545' Float Collar @ 8,856' MD (Top) Float Shoe @ 8,900' MD (Bottom) ' FC-1 RD Ninilchik Unit 1,898' FSL 8~ 2,885' FEL Sec. 6,T1 N, R12W, SM 1~ ~J u M MARA7110N Conductor 20" 97 ppf J-55 PE T~ Bottom MD 0' 248' TVD 0' 248' 4 112" X Nipple (3.813" ID) @ 5,387' MD Well Name: Falls Creek #1 RD Lease: Ninilchik Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,706 - 8,750' (TVD): 5,153' - 8,172' Angle @ KOP and Depth: 3,094' MD Angle @ Perfs: 45.5° Dated Completed: 41912002 Completion Fluid: 6 % KCL Revised by: James Ostroot Last Revison Date: 61112010 c f Permit #: 201-155 API #: 50-133-10005-01-00 Proa. Des: ADL - 00590 KB Elevation: 276' (21' AGL) X: 239,906 Y: 2,269,454 Latitude: 60 12' 15.857"N Longitude: 151 25' 46.322" W Re-Entry Spud: 07/3112001 Re-Entry TD: 08/1512001 Rig Released: Baker Chemical Injection Nipple @ 1,950' MD (top) 5,930" OD/3.858" ID 8,430 psi burst/7,500 psi collapse Top of Cement @ 2,650' MD KOP @ 3,094' MD (Top of Window) Whipstock set in 9-S18" @ 3,117' MD Build 5.0 deg1100' from 3,094-3,924' MD Max angle at 45.5 deg at 3,924' MD Drop 2 deg/100' to 7,700' MD Final angle @ 0.5 deg to TD at 8,900' MD Azimuth: 270 deg. CIBP @ +l- 3,151' (WLM) Cement Retainer @ 3,850' Cement Plug: 3,850' - 4,011' Cement Retainer @ 4,855' Cement Plug: 5,200' - 5,991' Casing Damage @ 5,315' Formation T ops: Formation Deoth Beluga 2,077' MD 2,063' TVD Tyonek 5,513' MD 4,972' TVD Tyonek T3 7,595' MD 7,017' TVD TD 8,900' MD 8,322' TVD Baker Model D @ 7,545' Cement Plug: 7,562' - 7,641' 2.7/8", 6.5 ppf, N-80 Srd Float Collar @ 8,856' MD (Top) Float Shoe @ 8,900' MD (Bottom) PROPOSED Falls Creek #1 RD Ninilchik Unit 1,898' FSL & 2,885' FEL Sec. 6,T1 N, R12W, SM k ~" ~~ '~ :* W i ;• ~~ ~. ~`~ Production Casing ~ 4-1/2" L-80 12.6 ppf Mod Buttress r~ Tom Bottom MD 0' 8,900' TVD 0' 8,322' -- - ' A 6-3/4" hole Cmt w/ 405 sks of 12.5 ppg Lead and 647 sks 15.7 ppg -~~,-; Tail, Class G i 9.5/8" N-80 40 ppf LTC TOE Bottom MD 0' 3,150' TVD 0' 3,071' 12.1/4" hole Cmt w/ 1884 sks of 12.5 ppg, Class G, Lead and 175 sks of 13.5 ppg, Class G, Tail Ori final Perfs: 3,900"-3,911' 5,290'-5,315' Wireline Fish: Consists of 1"fish neck 5,442'-5,470' with 1-7116" body on the wireline cable 7,562'-7,600' head, CCL, PX crossover sub, and 15' Sgz Floles: long 3-318" OD (spent) pert gun. 3,884'-3,886' 5,275', 5,326', 5,419', 5,490' ~~ M MARATMOM Conductor 20" 97 ppf J-55 PE TOP Bottom MD 0' 248' TVD 0' 248' 13-3/8" J-55 54.5 ppf STC T~ Bottom MD 0' 2,468' TVD 0' 2,440' 18-518" hole Cmt w/ 1,660 sks of 12.5 ppg, Class G (1.50" ~ to~box x 2.0" ID bottom) wireline re-entry guide 4112" X Nipple (3.813" ID) @ 5,387' MD Existing Tyonek Perts: MD TVD 5,706-5,736' 5,153'-5,182' Owen 3-3/8", 60 deg, 6spf 06/0712005 5,814-5,862' 5,256'-5,302' Owen 3-3/8", 60 deg, 6spf 06/06/2005 5,875-5,885' 5,315'-5,324' Owen 3-318", 60 deg, 6spf 0610612005 6,405'-6,438' 5,832'-5,864' Owen 3-3/8", 60 deg, 6spf 11/23/04 7,335'-7,367' 6,757'-6,789' Owen 3-3/8", 60 deg, 6spf 7/7/04. 7,403'-7,423' 6,825'-6,845' Owen 3-3/8", 60 deg, 6spf 7/6/04. 7,914'-7,934' 7,336'-7,356' Owen 2-3/8", 60 deg, 8spf (4SPF twice) 1/4/04 8,714'-8,750' 8,136'-8,172' Schlumberger 2-7/8" PJ 2906 6spf 4/08/2002 TD PBTD 8,900' MD 8,851' MD 8,322' TVD 8,273' TVD Well Name: Falls Creek #1 RD Lease: Ninilchik Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,706 -8,750' (TVD): 5,153' - 8,172' Angle @ KOP and Depth: 3,094' MD Angle @Perfs: 45.5° Dated Completed: 4/9/2002 Completion Fluid: 6 % KCL Revised by: Last Revison Date: M Marathon MARATHON Oil Company September 2, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~I SEP 0 4 2008 Alaska Oii ~ Gas i~a~s.~c~rsi~~~~~-, Reference: 10-404 Report of Sundry Well Operations An~'~f~~~~k~e 5 rn1 D, , ~~ Field: Ninilchik Unit d~ Well: Falls Creek 1 RD ~~i~N~~ SL? `~ ;x 200 Dear Mr. Maunder: Attached for your records is the Report of Sundry Well Operations 10-404 for FC-1 RD well. Twenty feet of perforations were added to the Tyonek formation under Sundry #303-385. This report is a reflection of the well arrangement at the time of work completion and does not represent the well's current configuration. Submission of this report is part of Marathon's ongoing effort to resolve the backlog of outstanding sundries. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~~~ s Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Operations Summary Kenai Well File KJS STATE OF ALASKA ~~~ 9~ AL OIL AND GAS CONSERVATION COM~SION p ®~ ~~Q~ PERATIONS~~ ~~~~~ REPORT OF SUNDRY WELL O i1 & ~~~ t.~Qn~' C~iti,s'~,j~~ti~ 1. Operations Abandon Repair Well Plug Perforations Stimulat A trr!~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q ~ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0' Exploratory^ 201-155 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-10005-01-00 7. KB Elevation (ft): 9. Well Name and Number: 276' (21' AGL) ~ Falls Creek 1 RD " 8. Property Designation: 10. Field/Pool(s): ADL - 590' Ninilchik Unit/ Tyonek Pool 11. Present Well Condition Summary: Total Depth measured $,gp0' ~ feet Plugs (measured) NA true vertical 8,322' " feet Junk (measured) NA Effective Depth measured 8,80g' feet true vertical 8,231' feet Casing Length Size MD TVD Burst Collapse Structural 2g' 36" 49' 49' Conductor 227' 20" 248' 248' 2,110 psi 520 psi Surface 2,447' 13-3/8" 2,468' 2,438' 5,020 psi 2,260 psi Intermediate 3,130' 9-5/8" 3,151' 3,087' 5,750 psi 3,090 psi Production g,g7g' 4-1/2" 8,900' 8,322' 8,430 psi 7,500 psi Liner Perforation depth: Measured depth: 7,914'-8750' gross True Vertical depth: 7,336'-8,172' gross Tubing: (size, grade, and measured depth) N/A N/A N/A Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 20' of perfortions were added to the Tyonek formation (7,914'- 7,934') during two gun runs utilizing 2-3/8" HSC, 60° phase, Treatment descriptions including volumes used and final pressure: 8spf guns. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 6,200 - 1,077 N/A Subsequent to operation: 0 10,000 - 1,420 N/A 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303-385 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician c ~ Signature ~ ~ Phone (907) 283-1371 Date September 2, 2008 Form 10-404 Revised 04006 (~ ~ ~ S' ~~'~'. ~~~ ~ ~ emit Original Only U GINAI. ~.-, • • M Marathon operations Summary Report nuwaraa tOilCorttpeny Well Name: FALLS CREEK 1 Daffy Operations Report Date: 72282003 Job Category. Other 2l Mr Srmmary Ran 3.80"" GR. Unable to pass X-nipple. Ran 3.60"" GR. Tagged fill ffi 8741' MD RIH wl AD2 stop and tandem quartz gauges. Set F-stop and gauges at 8695' MD. RDMO aline. Resume well production. opr SlartTlne ErC Tlne Drr 0 C ACaI CoOe S[atli rDk CO0t Canmert 09:00 11:00 2.00 RURD_ SLIK MIRU Expro muldiline truck. Well SI. Hammer up adaptor spool to crossover pressure, POOH w/ GR. 14:00 16:00 2.00 TAG_ BOTM Run 3.60"" GR. Run through x-nipple wl no problem. Tag fIN at 8741'MD. POOH. 16:00 19:00 3.00 RUNPUL SLIK Program gauges per directions. Start at - 16:10. RIH wI AD2 stop and gauge assembly. Have smaN problems at chemical injection mandrel, but pass through OK. Complete stops at 8550', 8600', 8 8650'. Set AD2 stop at 2.50 road gauges. Finish RD. Data will be sent to Louisiana for processing is expected Mon 1 /5. Return well to production and help set up unit for 6.5 MMscid. Pressure is steadil risin to 1600 si. 12:30 14:00 1.50 PERF_ MU and run 20' gun #2. Correlate to GR and perforate in same zone 7914'-7934' wdh well still flowing. POOH. 14:00 15:00 1.00 RURD_ PERF Rig wireline down from well. Open choke to original 52% setting. Fbw leveled off wdh ~ 10MMscfd lm 1450psi. Perforated 7914'-7934' w/ 2-3P8"" HSC, 60 deg phase, 8 spf (2 runs of 4 spf) with well flowing. Production changed from 6.2MMscfd @ 1077psi to 10MMscfd @ 1420psi. Opr StartTlne ErC71ne Drr 0 Otle ACiL COOP 56trr TroeDkC Canmert 09:00 11:00 2.00 RURD_ PERF RU Expro aline. MU 20' gun #1 wdh gamma ray. Pressure test lubricator with methanol. Well MMscid 1077 si. 11:00 12:30 1 .50 PERF_ RNi w120' guru #1 . Correlate and perforate 7914'-7934' wdh well flowing. POOH. Flowrate quickly increased to +g MMscid. Choke well to back to www.peloton.com data and returned well to production. Prepare wireline unit to -___~ri Report Printed: 8M82008 • ~arathon Oil Company Alaska Asset Team IYlarathon .~ ~ a;'~ ~~~ ~~;~' KeOna6 AK 99611 • ~~ ~ ; $ ~, z~~ :s- ~~ MARATHON O~I Company ~:~L,~.~'~` 7elephone 907/283-1371 MAY ~ ~ 2008 Fax 907/283-1350 c~~~. ~~r~-~`~~~~~~ 5 ~~as~a ~~~ ~ ~Cnor~~ ~ 5 May 15, 2008 O 1~ a Mr. Tom Maunder Alaska Oil & Gas Conservation Commission ~~~~`~~ ~~~~~~~ 5~~~ ~ 333 W 7th Ave ~~. °~-c ~,~.` e~.tLA (~ ~~ Anchorage, Alaska 99501 ~~ ~ ~~~C ~ Reference: 10-404 Sundry Submittal List ~ ~~ ~ ~~~5~ <s~."~~ ~~ ~~b~c~-, ~o ~, ~-- ~,~5~~-~ ~. ~ ~o ~. ~~ ~ e Dear Mr. Maunder: c,~c..~-~ct ~ v~c~ c-~ ~. ~~~ ~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to ~`~ ~--?~ P p J close out 10-403 Sundry approved well work activities. Work has been ongoing to ~~:}~~-~~ identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ ~ , <~~ =ti ~ t~C~~ '~~~,.~~~~'~~ _ `~ ~e~~i Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS r • M Marathon MARATHON Oil Company January 23, 2008 ~G~~~ ~/ ~L~ • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 MAY ~ 6 2008 Alaska Oii ~ Gas ~ons. Commissi~n ~nchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Ninilchik Unit Well: Falls Creek #1 RD Dear Mr. Maunder: Attached for your records is the 10-404 sundry report for well FC-1 RD. This sundry covers the addition of the Tyonek interval from 6405' - 6438'. The additional perforations were completed under sundry #304-414. The job was successfully completed. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, L Wayne E. Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW STATE OF ALASKA ~9 ' ALA~OIL AND GAS CONSERVATION COM~ION ~~~~'~E~ M/~Y ~ 6 200$ REPORT OF SUNDRY WELL OPERATIONS P~I~~ka C~if & Gas Cons. Commissio~~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~~~rage PerFormed: Alter Casing ~ Pull Tubing ^ PerForate New Pool ^ Waiver ^ Time Extension Change Approved Program ~ Operat. Shutdown ~ PerForate ^~ ~ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ~ Exploratory^ 201-155 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-1000~-01 7. KB Elevation (ft): 9. Well Name and Number: KB 276' Falls Creek #1 rd ~ 8. Property Designation: 10. Field/Pool(s): Falls Creek PA (ADL 590) Ninilchik Field/ Tyonek Pool undefined 11. Present Well Condition Summary: Add perforations from 6405' - 6438' Total Depth measured 8,900 ~ feet Plugs (measured) true vertical g,322 - feet Junk (measured) 15' Spent perF gun @ well bottom Effective Depth measured g,g5~' ° feet true vertical g,273'- feet Casing Length Size MD TVD Burst Collapse Structural Z$' 36" 28' 28' Conductor 248' 20" 248' 248' 2110 psi 520 psi SurFace 2468' 13-3/8" 2468' 2440' 2730 psi 2260 psi Intermediate 3150' 9-5/8" 3150' 3071' S750 psi 3090 psi Production 8900' 41/2" 8900' 8322' 8430 psi 7500 psi Liner Perforation depth: Measured depth: 6405'-8750' Gross True Vertical depth: 5832'-8172' Gross Tubing: (size, grade, and measured depth) N/A N/A N/A Packers and SSSV (type and measured depth) NIA N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 3,867 1.5 N/A 780 Subsequent to operation: 0 3,991 1.5 N/A 778 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Wel! Operations X 16. Well Status after work: Oil ^ Gas ~^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 304-414 `~ Contact Kevin Skiba (907) 283-1371 Printed Name Wayne E. Cissell Title Well Work Over Supervisorr R Signature Phone (907) 283-1308 Date January 23, 2008 Form 10-404 Revised 04/2006 ~ Submit Original Only ~ . ~ ~F~ <<~~~ 2 ~ 2009 ~ ~a~ • . . ; Marathon Oil Company Pa9e ~ of 2 Operations Summary Report . Legal Weli Name: FALLS CREEK 1 Common Well Name: FALLS CREEK 1 Spud Date: 1/1/1961 Event Name: RECOMPLETION Start: 7/6/2004 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations ; 'I 11/23/2004 08:00 - 11:30 3.50 CMPPRF Held PJSM discussed wire line procedure and enviriionmental concerns. Held off rigging up till sander made pass around the well head area and pad. MU a 3.7" GR. PU tool sting used WHP to test lubricator. Brought lubricator up slowly. LP= 100 psig high pressure = 800 psig. Flow rate on well at 3867 MCF at 1.5 BPD. WHP= 780 psig. 11:30 - 12:00 0.50 CMPPRF RIH with GR to 6400; POOH with GR. NO problems while running in well with GR. 12:00 - 13:30 1.50 CMPPRF MU CCL with 20' 3 3/8" gun, 6 SP. RIH correlate to Schlumberger log 8-15-2001 . Gun on depth to perforate from 6418' to 6438' DIL (20'). Shut well in to build tubing pressure prior to perforating wetl. WHP= 780 psig @3800 MCF. Shut well in at 1303 , WHP= 780 psig. 1311, Printed: 12l28/2007 9:44:45 AM . ~ ~ Marathon Oil Company Pa9e 2 of 2 - Operations Summary Report Legal Well Name: FALLS CREEK 1 Common Well Name: FALLS CREEK 1 Spud Date: 1/1/1961 Event Name: RECOMFLETION Start: 7/6/2004 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Cotle ~ode Phase Description of Operations 11/23/2004 12:00 - 13:30 1.50 CMPPRF WHP= 1188 psig. 1315, 1251 SHP= psig, 1320, WHP= 1305 psig well at 50% underbalance. Shot gun WHP= 1313 psig. POOH with gun. After 5 minutes WHP= 1430 psig. Open choke to production. Well flowing at 4000 MCF, WHP= 1240 psig. 13:30 - 14:00 0.50 CMPPRF OOH with gun #1, 20' All shots fired. WHP= 770 psig @ 3665 psig while RIH with gun #2. 14:00 - 15:00 1.00 CMPPRF RIH with gun #2. 13' - 3 3/8" gun loaded at 6 SPF. Correlate CCL with open hole log, depth to perforate is from 6405' to 6418' DIL. Made tie in pass with gun #2. Shut in well to build pressure same as before. WHP= 776 psig, 3670 MCF when well shut in. 15:00 - 15:50 0.83 CMPPRF Contacted operator to shut well in to build pressure on tubing. SIW at 1505 whp built to 1250 psig. Fired gun at 1531. Well prerssure up to at 1327 psig after 5 minutes, open well up to production. POOH with gun #2. 15:50 - 16:30 0.67 CMPPRF When at top of well with perforating gun. Operator thought he was at +33' in the well and crowned out the the tool string, pulled out the wire in the cable head and dropped the gun in well. Wire pulled out of the pack off and fell from the top sheave to ground. No one was around wire, shut well in and blew down lubricator. The wire line operator also indicated that he was pulling wire out of well at 115 FPM when he topped out. 16:30 - 16:50 0.33 CMPPRF Contacted Anchorage about fired gun in well. Decided to leave the gun and CCI. in bottom of well. Note: fish consists of (1" fish neck with 1 7/16" body) on the wire line cable head, CCL, PX cross over sub and 15" (shot) perf gun. "' all indications are that gun fired because of weight shift when shot RD wire line unit. WHP= 778 PSIG, 3991 MCF. 16:50 - 18:45 1.92 CMPPRF Turned well over to production, wire line crew left lease. Printed: 12/28/2007 9:44:45 AM ~ M Marathon MARATHON Oil Company R~~~~ V L,~ ~ Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 January 23, 2008 MAY 1 6 2008 Alaska Oii & Gas Cnns. ~ommission Anchorage Mr. Tom Maunder ~ Alaska Oil & Gas Conservation Commission t 333 W 7th Ave ~ h t~' V Anchorage, Alaska 99501 d`~" Reference: 10-404 Sundry Report Field: Ninilchik Unit Well: Falls Creek #1 RD ~~~~~~~ ' AiJ~ ,~ ~ 200~ Dear Mr. Maunder: Attached for your records is the 10-404 sundry report for well FC-1 RD. This sundry covers the addition of Tyonek perForations from 7403' - 7423' & 7335' - 7367'. The work was completed under sundry #304-204. Initial results were positive from adding the perforations. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, t Wayne . Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW STATE OF ALASKA S ~~ ~ ~ R~o/~i~C~ ALAS~IL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS MAY ~ 6 2008 1. Operations Abandon Repair Well Plug PerForations Stimulate 8S a I Of1S. Commissi~n Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extensjl~n~ra~e Change Approved Program ~ Operat. Shutdown ~ Perforate ~^ ~ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Pennit to Drill Number: Name: Marathon Oil Company Development ~~ ^ Ex lorato P ry ^ 201-155 3. Address: Stratigraphic ^ Service ~ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-10005-01 7. KB Elevation (ft): 9. Well Name and Numbee KB 276' ~ Falls Creek #1 rd ~ 8. Property Designation: 10. Field/Pool(s): Falls Creek PA (ADL 590)- Ninilchik Field/ Tyonek Pool 11. Present Well Condition Summary: Add perforations @ 7403' - 6423' & 7335'- 7367' Total Depth measured 8,900 . feet Plugs (measured) true vertical g,322 ~ feet Junk (measured) Effective Depth measured g,$5~' feet true vertical g,273' - feet Casing Length Size MD TVD Burst Collapse Structural 28' 36" 28' 28' Conductor 248' 20" 248' 248' 2110 psi 520 psi Surface 2468' 13-3/8" 2468' 2440' 2730 psi 2260 psi Intermediate 3150' 9-5/8" 3150' 3071' 5750 psi 3090 psi Production 8900' 41/2" 8900' 8322' 8430 psi 7500 psi Liner Perforation depth: Measured depth: 7335'-8750' Gross True Vertical depth: 6757'-8172' Gross Tubing: (size, grade, and measured depth) N/A N/A N/A Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 4,100 1.50 N/A 770 Subsequent to operation: 0 6,450 1.5 N/A 750 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exem : 304-204 Contact Kevin Skiba (907) 283-1371 Printed Name Wayne E. Cissell Title Well Work Over Supervisor G ~~, Signature Phone (907) 283-1308 a~ Date January 23, 2008 r Form 10-404 Revised 04/2006 ~~~~ ~~~ J~~L ~~~~~~ Submit Original Only ~ ~ Marathon 0il Company Operations Summary Report Legal Well Name: FALLS CREEK 1 Common Well Name: FALLS CREEK 1 Event Name: RECOMPLETION Start: 7/6/2004 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code Code Phase 7/7/2004 10:30 - 11:00 0.50 RURD SLIK CMPPRF 11:00 - 11:30 0.50 SAFETY SMTG CMPPRF 11:30 - 13:30 2.00 RURD SLIK CMPPRF 13:30 -14:00 0.50 RURD SLIK CMPPRF 14:00 - 15:30 1.50 RUNPU EQIP CMPPRF 15:30 - 16:30 1.00 RUNPU EQIP CMPPRF 16:30 - 17:00 0.50 RURD SLIK CMPPRF 7/8/2004 07:00 - 0730 0.50 SAFETY SMTG CMPPRF 07:30 - OS:00 0.50 RURD SLIK CMPPRF 08:00 - 08:30 0.50 RURD SLIK CMPPRF 08:30 - 09:30 1.00 RUNPU EQIP CMPPRF 09:30 - 10:30 1.00 RUNPU EQIP CMPPRF 10:30 - 11:30 1.00 RUNPU EQIP CMPPRF 1130 - 13:00 1.50 RUNPU EQIP CMPPRF 13:00 - 14:30 1.50 RURD SLIK CMPPRF Page 1 of 2 Spud Date: 1/1/1961 End: Group: Description of Operations Move in Expro wireline to perforate new Tyonek intervals. Spotted wireline unit and mast truck. Well flowing 4.1 MMscfd at 770 FTP. Late start due to change of plans setting plug at KGF well. Held PJSM to discuss potential hazards and operational plan. RU Expro equipment. Shut in well to build pressure for underbalance perforating. Flange up pump-in tee and wireline vaive. MU lubricator. MU Gun-GR and armed perforating gun. Take lubricator to wellhead. Pressure test with well gas to 1300 psi. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311NT3, 25 gm. charges, 6 SPF on Gun-GR. Correlated depth with Schlumberger Array Induction openhole log run Aug-15-2001. Well shut in while running in hole with SITP at 1300 psi. Perforated 7403-7423' KB with 1300 psi WHP. Pressure built from 1300 to 1380 psi in 5 minutes. POOH with gun - all shots fired and round. Flowed well while pulling out of the hole. Well flowing at 3.3 MMscfd at 750 psi one hour after perforating. Closed swab valve and blew down lubricator. LD lubricator and MU night cap to top of wireline vaive. Plan to finish perforating tomorrow. Held PJSM to discuss potential hazards and operational plan. Expro warmed up equipment. Layed out and armed 20' 3-3/8" OD perforating gun. PU lubricator and puiled gun into lubricator. Took lubricator to wellhead. Pressure tested lubricator with WHP to 800 psi. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. CoRelated depth with Schlumberger GR-CCL strip log run Apr-09-2002. Well flowing at 4.45 MMscfd at 750 psi while running in hole. Perforated 7347-736T KB with 1150 psi WHP. Pressure built from '1150 to 1390 psi in 3 minutes and to 1470 psi in 10 minutes. POOH with gun - all shots fired and round. Flowed well while pu~ling out of the hole. Armed 15' 3-3/8" carrier and RIH with 3.375" OD perforating gun loaded 12' with SDP-3125-311NT3, 25 gm. charges, 6 SPF on CCL. Corcelated depth with Schlumberger GR-CCL strip log run Apr-09-2002. Well flowing at 6.45 MMscfd at 750 psi while running in hole. PerForated 7335-7347' KB with 1630 psi WHP. Pressure built from 1630 to 1720 psi immediately and to 2050 psi in 15 minutes. POOH with gun - all shots fired and round. Flowed well while pulling out of the hole. RDMO Expro wireline. Returned well to sales. PriMed: 12/28/2007 9:44:45 AM . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc 0_° ~~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 S¡?i.d J I J~1~ ~~ I Permit to Drill 2011550 Well Name/No. NINILCHIK UNIT, FALLS CK 1 RD Operator MARATHON OIL CO API No. 50~133-10005-01-00 MD 8900 ...-- TVD 8322 ", Completion Date 4/9/2002"'----- Completion Status 1-GAS ----.----- - -------------- REQUIRED INFORMATION Mud Log No Samples No ~--~----- -.- -- ---. ----- ------ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name - .--- ------- ....i...2D C ¿µ¡669 Neutron :~ T Að248 !~ T ~252 !:I"T j.,(\-$ '-ffi311 J",~ Îv.-.· ~ C ~~52 ~ C v10248 , Rpt l~_ _C__~~_ ¡µ>311 ~ \ -( ì~~ r ) Well Cores/Samples Information: Log Log Run Scale Media No 1 Berrr;;;:n Log 2 FINAL FINAL FINAL FINAL FINAL Final Well Report Name Interval Start Stop 3094 8900 Received Sent ---------- - -----~ Cuttings --------~ ADDITIONAL INFORM~I(_ TION Well Cored? Y ~ Daily History Received? Chips Received? ~ Analysis ~ Received? Formation Tops ~ _._----------~ -- --~--------- -------- Comments: Current Status 1-GAS UIC N Directional S~N,O '- ) (data taken from Logs Portion of Master Well Data Maint) --..--' Interval OH/ Start Stop CH Received Comments 2790 8905 Open 317/2002 3105 8900 Open 8/30/2001 3105-8900 2790 8905 Open 8/28/2001 2790-8905 2790 8905 ~ 9/21/2001 2790-8905 ,*, 3105 8900 Open 8/30/2001 3105-8900 Sepia 2790 8905 Open 8/28/2001 2790-8905 digital data Open 8/30/2001 Digital Data Open 8/30/2001 Final well report 2790 8905 ~ 9/21/2001 2790-8905 Digital Data Sample Set Number Comments -- 1064 ·~N @N DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2011550 Well Name/No. NINILCHIK UNIT, FALLS CK 1 RD Qperator MARATHON OIL CO API No. 50-133-10005-01-00 MO 8900 NO 8322 fJ::0n Date 4/9/2002 Completion Status 1-GAS Current Status 1-GAS UIC N Date: ). ¡;, J" 1 ~ '" \ )- --- -- -- ------ - ----------- ---- Compliance Reviewed By: -' ,------ ) ) FRANK H. MURKOWSKI GOVERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 Mr. John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, #100 Anchorage, Alaska 99501-3539 R" ECE \" " ..¡ ',,-..m '""", .,#,,,.,- JUN 2 ~l~ 2005 June 20, 2005 :M~~$~Œ~ Oi~ (Sl Subject: Expiration of extended confidentiality under 11 AAC 83.153 ;1.\'1 j - P...., $- Marathon Falls Creek lRD API 501331000501 Marathon Grassim Oskolkoff#1 API 501332049300 Marathon Grassim Oskolkoff#2 API 501332050300 Marathon Susan Dionne #1 API 501331000201 Marathon Susan Dionne #3 API 501332051200 John, The terms of extended confidentiality granted on June 19, 2003, for the subject well data pursuant to 11 AAC 83.153 expired yesterday, June 19, 2005. The well data are subject to release today, June 20, 2005. The operator, Marathon Oil Company, was considering a request for a second extension, but confirmed today that a second extension will not be sought. Regards,. ~ ¡Ø, . . d7 I/) ~~vé~ 1/' - ~~/M.ark D. Myers to DIrector Cc: J. R. Cowan, Division of Oil and Gas Jeff Landry, Department of Law UDevelop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " 6/23/2005 8: 18 AM "2-ol-I-S-~- 1 of 1 John K. N orman <I.2hp._....:Ng.æ!.ªP.:@.ª-~!.rr!i!.!.:.§.!.~.t~:.~§> Commissioner Alaska Oil & Gas Conservation Commission Jim Cowan Manager, Resource Evaluation State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 Phone: 907-269-8765 Fax: 907-269-8938 or 8942 Email: jc@dnr.state.ak.us A formal letter will follow. API 501331000501 API 501332049300 API 501332050300 API 501331000201 API 501332051200 The wells in question are: Marathon Falls Creek 1RD Marathon Grassim Oskolokoff #1 Marathon Grassim Oskolokoff #2 Marathon Susan Dionne #1 Marathon Susan Dionne #3 The term of extended confidentiality for the following wells expired yesterday and the wells are subject to disclosure today, June 20, 2005. Marathon was considering requesting a second extension, but Brock Riddle confirmed by telephone this morning that a second extension will not be sought. Consequently the well data can be released immediately. John, Jim I thought I sent this yesterday, but apparently not. Jim Cowan wrote: John Got it! Thanks Jim. Subject: Re: Extended confidentiality expiration - Marathon Ninilchik Unit wells From: John Norman <john_norman@admin.state.ak.us> Date: Wed, 22 Jun 2005 10:29:08 -0800 To: jim_cowan@dnr.state.ak.us CC: howard_okland@admin.state.ak.us,"MarkD. Myers" <mark_myers@dnr.state.ak.us> ') ) Re: Extended confidentiality expiration - Marathon Ninilchik Unit wells . . ') ) . , M MARATHON - Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 June 10,2005 dvC \" \ ç¡; Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 R·..·· E~,¡ (~F . '.f.'¡::fi ,. 11~.,¡~il' i ,'" ':':'/;~' J UN· .~ ~ "I 0, ()C).'" .. ,,1) {., " ~nk Dear Mr. Aubert: Attached and submitted for your approval is the Form 10-404 detailing completed operations to perforate additional Tyonek gas pay in the Falls Creek #1 RD well bore. Also attached for your records is the revised well schematic and operational summary. If you require other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, t~~'\ÀJ~ Ken D. Walsh Senior Production Engineer Enclosures 1"".'~ \,.~\'; (~: ì f\j /~ L \....~ l \ '-.) ~ ~ \j 1'"\ '\ STATE OF ALASKA ') ALA~..A OIL AND GAS CONSERVATION COMMISSION 0.',,". . .~ i'" .,_ REPORT OF SUNDRY WELL OPERATIONS f{E E~VE:: StimulateU ~~Å'r\ L1J :]1 Z005 Waiver D Tlm6 EX!t:n~j.or¡ 0 'II . Re-enter S'J~p~nb~d'W~~~Q :m~~,~: 5. Permit to Drill f4MÇ¡H~~~!ø\(¡. ExploratoryD 201·155 Service D 6. API Number: 50-133-10005-01 Total Depth measured 8900' M D feet true vertical 8322' TVD feet Effective Depth measured 8851' feet true vertical 8273' feet Casing Length Size MD Structural 28' 36" 28' Conductor 248' 20" 248' Surface 2468' 13-3/8" 2468' Intermediate 3150' 9-5/8" 3150' Production 8900' 4/1/2" 8900' Liner Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 3460 0 772 12,540 1 1305 15. Well Class after proposed work: Exploratory D Developm ent 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: Repair Well U Pull Tubing D Operat. Shutdown D Marathon Oil Company 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 7. KB Elevation eft): 276' 8. Property Designation: Falls Creek PA (ADL 590) 11. Present Well Condition Summary: Perforation depth: Measured depth: 5706-5736' True Vertical depth: 5153-5182' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run N/A Daily Report of Well Operations Attached Contact Ken D. Walsh Printed Name Ken D. Walsh Signature I~\J.\'J~ Form 10-404 Revised 04/2004 Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development D Stratigraphic D 9. Well Name and Number: Ninilchik Unit, Falls Creek #1 RD 10. Field/Pool(s): Ninilchik/Tyonek Plugs (measured) 0 Junk (measured) 0 TVD 28' 248' 2440' 3071' 8322' Collapse N/A 520 psi 1130 psi 3090 psi 7500 psi Burst N/A 2110 psi 2730 psi 5750 psi 8430 psi 5814-5862' 5875-5885' 5256'-5302' 5315-5324' N/A N/A RBDMS 8Fl J UN 1 4 2005 Tubing Pressure N/A N/A Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-105 Title Senior Production Engineer Ph.one. 90. ,f-~. ' 3-r11 OR,·1C¡f\ t \.J\ i\!· Date 6/10/2005 Submit Original Only 21. KB AGL (276' KBElev¡,¡tion) API #50-133.10005-01-00 Permit # 201-155 Property Deslønation: F¡,¡lIs Creek PA (ADL 590) WBS#WO.O.5.12098.EXÞ X=239,906 Y=2,269.454 Lat: 60 12' 15.857" N Lona:' 15125'46.322" W Re-entrvSpud: 0713112001 Re-entrvTD: 0811512001 Formation Tops: Formation Beluga Tyonek Tyonek T3 TD Depth (MD) Depth (TVD) 2077' 5513' 7597' 8900' ) 2057' 4967' 7013' 8322' ) Falls Creek #1 RD Ninilchik Unit 1898' FSL & 2885' FEL Sec.6-T1N-R12W ~ i í ~.":I' ~¡ ì I '" ~ ~I ~ ~ t~ ~'~ .~ i ~ I ! ",::".'. I It.W ~}ó ~ ~ ~ ~ " ~ ~,' ~ ... ¡,' 'j .... ~i,l~ ~ J, i Î ~I ~1¡¡ ~ ~ ~ ~/14112!' X Nipple (3.813"ID)@5387'MD ~¡ ~ ",'. (,': U~ M ExistinQ Tvonek Perfs: ~ ~ MD TVD ~,','.'~ ~" 5706·5736' 5153'·5182' Owen 3·318", 60 deg, 6spf 0610712005 , $: 5814·5862' 5256'·5302' Owen 3·318",60 deg, 6spf 0610612005 ~~ t~ 5875-5885' 5315'-5324' Owen 3·318", 60 deg, 6spf 0610612005 -~ ~ :~ ~ -~. ~.,.-- > "': I) ,: " ~ f, b :~ ~ ~ '~ 'I ~ I'i ~~ ~~Îr.. A Wireline Fish: Consists of 1" fish neck with 1 7/16" body on the wire line cable head, eel, PX cross over sub, and 15' long 3-3/8" 00 (spent) perf gun. TD: 8900' MD / 8322' TVD , ' M. MARATIIOI ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Conductor 20" 97 ppf !QR.. 0' 0' ~ MD TVD J·S5 Bottom 248' 248' PE ~cementToP at 2650' MD I Surface CasinQ 13-3/8" 54.5 ppf !QR.. 0' 0' J·55 STC Bottom MD TVD 2507' 1772' 18·518" hole with 1660 sks cement Intermediate CasinQ 9·518 " 40 ppf !QR.. 0' N·80 Bottom LTC MD TVD 3150' 3071' 0' 12·114" hole with 1884 sks cement , 6405' . 6438' 7335' . 7367' 7403'·7423' 7914'·7934' 8714' . 8750' 5832'·5864' 6757'·6789' 6825'·6845' 7336'·7356' 8136'·8172' Owen 3·318", 60 deg, 6spf 11123104 Owen 3-318", 60 deg, 6spf 717104. Owen 3·318", 60 deg, 6spf 716104. Owen 2·318", 60 deg, 8spf (4SPF twice) 114104 Schlumberger 2-718" PJ 2906 6 spf 410812002 Production Casinq 12.6 ppf L-80 Mod Buttress !QR.. Bottom MD 0' 8900' TVD 0' 8322' 6·3/4" hole with 405 sks 12.5 ppg Lead and 647 sks 15.7 ppg Tail 4-1/2" ) ) Marathon Oil Company Operations Summary Report Filled out and reviewed MOC Safe Work Permit with Expro and Marathon personnel. Also reviewed and attached Expro Tailgate Form. Well made 3460 Mcfd at 772 psi FTP yesterday. MIRU Expro Wireline to add new Tyonek perforations. Spotted crane and wireline unit. Installed wireline valve and pump-in tee. Armed 10' 3-3/8" carrier with PX-1 and pull into lubricator. Take lubricator to tree. Pressure test lubricator with 780 psi SIWHP. 2.00 RUNPUL ELEC CMPPRF RIH with 3.375" 00 perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR/CCL. Attempted to correlate depth with Schlumberger Array Induction log run Aug-15-2001. Ran strip log twice but could not match GR traces well enough. Decided to POOH with live gun and swap out Gun GR/CCL. Reviewed and discussed disarming protocol. 0.50 RUNPUL ELEC CMPPRF Disarmed PX-1 firing head and swapped out Gun-GR/CCL. Armed firing head and took gun and lubricator to wellhead. 1.00 RUNPUL ELEC CMPPRF RIH with 3.375" 00 perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR/CCL. Correlated depth with SchlumbergerArray Induction log run Aug-15-2001. Ran strip log from 6050'-5250' MD. Choked back well production to achieve a SITP of 1100 psi while perforating. 1.00 PERF _ CSG_ CMPPRF Perforated 5875-5885' KB with 1100 psi WHP. WHP climbed to 1440 psi after 5 minutes. Opened well to sales monitoring rate and FTP while POOH with gun. All shots fired and round. One hour after perforating this interval, rate is 7271 Mscfd at 1140 psi FTP (EFM at 53%). 0.50 RUNPUL ELEC CMPPRF RIH with 3.375" 00 perforating gun loaded 24' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth with strip log. Choked back well production to achieve a SITP of 1100 psi while perforating. 1.00 PERF _ CSG_ CMPPRF Perforated 5838-5862' KB with 1180 psi WHP. WHP climbed to 1535 psi after 5 minutes. Opened well to sales monitoring rate and FTP while POOH with gun. All shots fired and round. One hour after perforating this interval, rate is 7088 Mscfd at 1340 psi FTP (EFM at 55%). RIH with 3.375" 00 perforating gun loaded 24' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Correlated depth with strip log. Perforated 5814-5838' KB with 1410 psi WHP. WHP climbed to 1563 psi after 5 minutes. Opened well to sales monitoring rate and FTP while POOH with gun. All shots fired and round. RD Expro from well and stood back equipment. Will try to maintain 10 MMscfd overnight and monitor FTP (ensuring that it does not dip below 1100 psi). Will check with Team in AM to decide whether to perforate 5706-5736' MD or standdown perforators. Filled out and reviewed MOC Safe Work Permit with Expro and Marathon personnel. Also reviewed and attached Expro Tailgate Form. Well flowed steadily at 10 MMcfd at 1320 psi FTP overnight. RU Expro Wireline to add new Tyonek perforations. Installed wireline valve and pump-in tee. Armed 30' 3-3/8" carrier with PX-1 and pulled into lubricator. Took lubricator to tree. Pressure tested lubricator with 1325 psi WHP. 0.50 RUNPUL ELEC CMPPRF RIH with 3.375" 00 perforating gun loaded 30' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR/CCL. Correlated depth with Expro GR/CCL strip log run Jun-06-2005. Choked back well production to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: FALLS CREEK 1 FALLS CREEK 1 RECOMPLETION Date From - To Hours Code Sub Phase Code 6/7/2005 07:00 - 07:30 0.50 SAFETY MTG - CMPPRF 07:30 - 09:30 2.00 RURD - ELEC CMPPRF 09:30 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 1.00 RUNPUL ELEC CMPPRF 16:30 - 17:00 0.50 PERF - CSG_ CMPPRF 17:00 - 18:00 1.00 RURD - ELEC CMPPRF 6/8/2005 07:00 - 07:30 0.50 SAFETY MTG - CMPPRF 07:30 - 08:30 1.00 RURD - ELEC CMPPRF 08:30 - 09:00 Page 1 of 2 Start: 6/6/2005 Rig Release: Rig Number: Spud Date: 1/1/1961 End: Group: Description of Operations Printed: 6/9/2005 4:12:24 PM '~ ') ') Marathon Oil Company Operations Summary Report Page 2 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: FALLS CREEK 1 FALLS CREEK 1 RECOMPLETION Start: 6/6/2005 Rig Release: Rig Number: Spud Date: 1/1/1961 End: Group: Date From - To Hours Code Sub Phase Code 6/8/2005 08:30 - 09:00 0.50 RUNPUL ELEC CMPPRF 09:00 - 10:00 1.00 PERF - CSG - CMPPRF Description of Operations 10:00 - 11 :30 achieve a SITP of 1300 psi (13.2 MMscfd instantaneous) while perforati ng. Perforated 5706-5736' KB with 1300 psi WHP. WHP climbed to 1450 psi after 5 minutes, 1590 psi after 10 minutes, and 1596 psi after 20 minutes. Opened well to sales monitoring rate and FTP while POOH with gun. All shots fired and round. One hour after perforating this interval, rate is 10.1 MMscfd at 1400 psi FTP (EFM at 65%). 1.50 RURD_ ELEC CMPPRF RDMO Expro Wireline. Left well flowing to sales. Printed: 6/9/2005 4:12:24 PM .. '~i. ~~ '7"':;\ ~ ~ ~ II-=-] ii, :\;kJ tl!Fï !"" II ;,i' i r ,~ \ 'I ,I :} ,1~', 'I J I 'i '\\ ;1:1 :i/'\'" :1:1 ;1 ~ ~=j" ¡) J :¡ il i;i~ '\ kU: f id \~ W ib&~ ¡!; ~ fr ) ffi~ ~ FRANK H. MURKOWSKI, GOVERNOR AI..A~K& OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken Walsh Senior Production Engineer U nocal PO Box 1949 Kenai, AK 99811 J.þ1-IS5 Re: N inilchik U nit, Falls Creek # 1 RD 305-105 Dear Mr. Walsh: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23 ay following the date of this letter, or the next working day if the 23rd day falls Q a he liday or weekend. A person may not appeal a Commission decision to Super' r Co unless rehearing has been requested. DA TED this~ day of April, 2005 Enc!. ') ) . , M MARATHON , Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 May 25, 2005 RECEIVED APR 2 7 Z005 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Alaska Oil 81: Gas Cons. Commission Anchorage Dear Mr. Aubert: Attached and submitted for your approval)s the Form 10-403 to perforate additional Tyonek gas pay in the Falls Creek #1 RD wellbore. This well is an active Tyonek gas / producer. Also attached for your records is the well schematic, and proposed operational procedure. If you would like any other information, please contact me at 283- 1311 or kdwalsh@marathonoil.com. Sincerely, '~b. eJM,- Ken D. Walsh Senior Production Engineer Enclosures ORIGINAL µGA- 4/2.1/2.00$ I;)1'S 1-1<3/0' ) STATE OF ALASKA ') AlAS'r~ Oil AND GAS CONSERVATION COMMk ,JON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: /" Development [] Exploratory D D 6. API Number: 50-133-10005-01 / Abandon U Alter casing D Change approved program D 2. Operator Name: 1. Type of Request: MARATHON OIL COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 7. KB Elevation (ft): 276' 8. Property Designation: Falls Creek PA (ADL 590) 11. Total Depth MD (ft): 8900' MD Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8322' TVD Length 28' 248' 2468' 3150' 8900' 0' Suspend U Repair well D Pull Tubing D PerforateL::J Waiver U Annular Dispos. U Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 201-155 /" Stratigraphic D Service 9. Well Name and Number: Ninilchik Unit, Falls Creek #1RD 10. Field/Pools(s): NinilchiklTyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): 8851' Effective Depth TVD (ft): 8273' Plugs (measured): Junk (measured): Size MD TVD 28' 28' 248' 248' 2468' / 2440' 3150' 3071' 8900' 8322' 0' 0' Tubing Grade: Perforation Depth MD (ft): 5706-5736' -~ 5814-5862' 5875-5885' Packers and SSSV Type: N/A 12. Attachments: Description Summary of Proposal U Detailed Operations Program [] BOP Sketch D Perforation Depth TVD (ft): 5153-5182' 5256'5302' 5315-5324' 36" 20" 13-3/8" 9-5/8" 4/1/2" o Tubing Size: N/A Packers and SSSV MD (ft): / Burst Collapse N/A 520 psi 1130 psi 3090 psi 7500 psi N/A 2110 psi 2730 psi 5750 psi 8430 psi Tubing MD (ft): 13. Well Class after proposed work: Exploratory D Development [] Service D 15. Well Status after proposed work: Oil D Gas [] / Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name. Ken D. Walsh fI n Title Senior Production Engineer Signature J~ b. \J....~~ Phone 907-283-1311 Date 5/4/2005 Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D 4/25/2004 Sundry Number: :JrJ5 -·/05 BOP Test D Mechanical Integrity Test D Location Clearance ~ 2Soo PÇA", Other: TI s t- 4-0 ~. RBDMS BFL M,A Y 0 2 2005 BY ORDER OF COMMIS'I~, E~ PI ¡ Ô -HE COMMISSION o R l=.7 ~ ~ \j 1"'\ L DRECEIVED APR 2 7 2005 Alaska Oil & Gas Cons. Commission Anchorage Date:Ø4{ ) 21' KB AGL(276' KB.Elevation} API' #5().133.10005.01.00 Permit # 201-155 Proøert\l Designation: Falls Creek PA (ADL 590) WBS# WO.Ò5.12098.EXP X~239.906 Y=2.269,454 Lat: 60 12'15.857"N Lona: 15125' 46.322" W Re.entrvSÞûd: 07/31/2001 Re~entrvTD: 08/15/2001 Formation Tops: Formation Beluga Tyonek Tyonek T3 TD Depth (MD) Depth (TVD) 2077' 2057' 5513' 4967' 7597' 7013' 8900' 8322' Wireline Fish: Consists of 1" fish neck with 1 7/16" body on the wire line cable head, eeL, PX cross over sub, and 15' long 3-3/8" CD (spent) perf gun. TD: 8900' MD / 8322' TVD ) ~j;~IVED (Dtlp 2005 Falls Creek #1RD /" Ninilchik Unit 1898' FSL & 2885' FEL Sec.6-T1N-R12W .. Ii! - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ l :~ Alaska Oil & Gas Cons. Comm;ssirm Anchorage Conductor 20" 97 ppf J·55 PE !mt Bottom MD 0' 248' TVD 248' .. ~ ~ ~"r ~~ ~'" I ! I ~ îiJ: ~.. ~~ \~.~ ~ .~.. ~'" ~ ~ I ~ t\ ~~ ~ ~ ~ ~ ~¡, ~J .... ~ ~'1, .... Vi ~ t,: i '~."~ i I ,,' ,.:' ;; ~,II ~ ~ /141/2" X Nipple (3.813" ID) @ 5387' MD ~ ~.. ')I ): ~ ~--1 Existina Tvonek Perfs: ~ , ~ 6405' . 6438' MD Owen 3-3/8", 60 deg, 6spf 11/23/04 Q ß 7335' - 7367' MD Owen 3·3/8", 60 deg, 6spf 7/7/04. , 10' 7403' - 7423' MD Owen 3·3/8", 60 deg, 6spf 7/6/04. ~,; ,I" 7914' - 7934' MD Owen 2-3/8", 60 deg, 8spf (4SPF twice) 1/4/04 -~ ~ 8714' - 8750' MD 2·7/8" PJ 2906 6 spf =~~ .e _1'- ~ Proposed Tvonek Perfs: -I. ~,.- ; J: ~~ ;~~ ~ ~ . ... .... i,~ i~ .- ¡ ~ .~ ~~ ~~i;i Surface Casinq 13·3/8" STC 54.5 ppf !mt 0' 0' J·55 Bottom - ,,'" 2507' t', 1772' MD TVD 18·5/8" hole with 1660 sks cement Intermediate Casinq 9·5/8" 40 ppf !mt 0' 0' N·80 LTC Bottom // 3150' 3071' MD TVD 12-1/4" hole with 1884 sks cement // , / 5706·5736' MD Owen 3-3/8", 60 deg, 6spf 5814-5862'~ Owen 3-3/8",60 deg, 6spf 5875·5885' MD Owen 3-3/8", 60 deg, 6spf Production Casinq 12.6 ppf L-80 Mod Buttress !mt Bottom / MD 0' 8900' TVD 0' 8322' 6·3/4" hole with 405 sks 12.5 ppg Lead and 647 sks 15.7 ppg Tail 4-1/2" ORIGINAL ) ) , , M MARATHON ~ MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Falls Creek #lrd Perforate Additional Pays WBS # WO.05.12098.EXP (Class 1 Pays) 04/25/2005 RECEIVED APR 2 7 2005 Alaska Oil & Gas Cons. Commission Anchorage / Objective: Perforate additional 88' net Tyonek over three intervals: 1) Hold PJSM with Expro Wireline and MOC personnel. Complete Work Pennit fonn. Deliver methanol test trailer and Ninilchik air compressor to location. 2) MIRV Expro to perforate new Tyonek intervals. Install BOPE with pump in sub to , 4-1//8" 5K tree. Install sufficient lubricator for 30' of3.375" perforating guns. /' /"./') 3) MV perf?rating equipment including CCL anr1~'Z.R'{ OD, 6 SPF perforating gun loaded wtth 3-1/8", SDP-3125-311NT3 charges~'" Note: Maximum gun swell in air is 3.635" O.D. with an average entrance hole of // 0.36" and penetration of 40.25". Pull perforating assembly into lubricator. MU lubricator to wireline BOP. Test /" BOPE and lubricator to 250/2500 psi. 4) RIH with perforating guns adjusting choke to achieve a SITP of 1100 psi (50% // underbalance) when each interval is perforated. 5) Correlate and Perforate. Correlate to Schlumberger cased hole bond log after adjusting to Array Induction open hole logging depth. Perforate intervals listed below starting with the deepest interval and working uphole. Immediately begin POOH with gun after perforating. Note rate of surface pressure build for 5 minutes. Then open well back up to flow while POOH with spent gun and RIH with next new gun. 5706' - 5736' MD (5153'-5182' TVD) ---- 30 ft ./ 5814' - 5862' MD (5256'-5302' TVD) ---- 48 ft / 5875' - 5885' MD (5315'-5324' TVD) ---- 10 ft /" 6) RDMO Expro. 7) Flow well to production facility. OR\C~:I l\¿ ') J.' I' ~~fÆ~E L:r !ÆLfÆ~~«fÆ AI..ASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken Walsh Marathon Oil Company PO Box 1949 Kenai AK 99611 Re: Falls Creek # 1 RD 304-414 Dear Mr. Walsh: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer' than one year. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a ho . or weekend. A person :~~e~~~ppeal a Commission deCi(;:riO~ u less rehearing has been J ~{. 0 BY ORDER OF THE COMMISSION DATED thisØay of November, 2004 '-- Enc!. ) ~L!Æ~E :.? !Æl!Æ~~!Æ ALASIiA OIL AND GAS CONSERVATION COMMISSION Ken Walsh Advanced Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, Alaska 99611-1949 Re: Palls Creek # 1 RD Sundry Number: 304-414 Dear Mr. Walsh: ) FRANK H. MURKOWSK/, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 do I ~ I!7S~ Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ( BY ORDER OF THE COMMISSION DATED this I~day of November, 2004 Enc!. " .", ) Alaska Business Unit M MARATHON t ~ Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 November 1, 2004 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your approval is the Form 10-403 to perforate additional Tyonek gas pay, 6405'-6438' KB, in the Falls Creek #1RD wellbore. This well is an active Tyonek gas producer. Also attached for your records is the well schematic, and proposed operational procedure. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, I~ b. \AJ~ Ken D. Walsh Advanced Production Engineer Enclosures ~I;'\ .lft,''''''''' .[~. ':', '\P) j~f . ,:¡.--:-,s¡ ¡ _--:¥ ';\ \t' ~..,,"" / NO V 1 f., 'l004 íW. \t-16/\- ìi ¡ 12./ 1..00 + ') STATE OF ALASKA ) C7j ¡ I ( J <..//1 ALAb,~ OIL AND GAS CONSERVATION COMI\tIo.JSION ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: I~XPloratOry 0 Service 0 Abandon U Alter casing 0 Change approved program 0 2. Operator Name: MARATHON Oil COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 7. KB Elevation (ft): 276' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 6405' - 6438' MD Packers and SSSV Type: N/A 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/15/2004 Oil 0 Gas 0 / Plugged 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact :~:::ame \(l:~W:~~ Phone 907-~:1311 AdvancedProdU::Engineer COMMISSION USE ONLY 1. Type of Request: 8. Property Designation: Falls Creek PA (ADl 590) 11. Total Depth MD (ft): 10668' MD Suspend U Repair well 0 Pull Tubing 0 Perforate ~ Waiver U Annular Dispos. U Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201.,.155 / Development Stratigraphic o o 6. API Number: 50-133-1 PQ~~-01 / ~~"~_. _;L~I' ,~:'\'" , II \\ A,,::~' Total Depth TVD (ft): 8468' TVD 9. Well Name and Number: Falls Creek #1 RD / 10. Field/Pools(s): NinilchikITyonek PRESENT WEll CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10597' 8397' filO V ç 1 0 2004 Plugs (measured): ¡,'"' ~ l,f f~~7'~(:".r :,. )-~ -J~,Ilt< (measdrè~;~~í1 Length Size MD TVD 28' 36" 28' 28' 248' 20" 248' 248' 2468' 13-3/8" 2468' 2440' 3150' 9-5/8" 3150' 3071' 8900' 4/1/2" 8900' 8322' 0' 0 0' 0' Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 5832-5864' TVD N/A Packers and SSSV MD (ft): Burst N/A 2110 psi 2730 psi 5750 psi 8430 psi Collapse N/A 520 psi 1130 psi 3090 psi 7500 psi Tubing MD (ft): Service 0 o Abandoned o WDSPL o o 11/4/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 70 l{. 4/ '-I Plug Integrity 0 Other: Subsequent Form Required: BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RBDMS BFL NOV 1 ; 7nn~ BY ORDER OF Date: SUb~i1!/ ---- INSrRg~~EVERSE THE COMMISSION ') ) MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Falls Creek #lrd Perforate Additional Pay WBS # WO.04.11190.CAP (Class 2 Pay) 11/01/2004 Objective: Perforate additional 33' Tyonek zone, 6405' - 6438' MD/5832'-5864' TVD. 1) MIRU Expro perforators. a. Hold P IBM and complete Work Permit form. Deliver methanol test trailer and Ninilchik air compressor to location. b. Install BOPE with pump in sub to 4-1//8" 5K tree. c. Install sufficient lubricator for 20' of3.375" perforating guns. d. MU CCL and 20' 3.375" aD, 6 8PF perforating gun loaded 20' with 3 1/8", 8DP-3125-311NT3 charges. Maximum gun swell in air is 3.635" O.D. with an average entrance hole of 0.36" and penetration of 40.25". e. PU and MU lubricator to wireline BOP. Test BOPE and lubricator to / 250/3000 psi. f. While RIH with perforating guns on each separate run, choke production rate to achieve a 8ITP of 1300 psi (50% underbalance) when each interval is' " perforated. Immediately begin POOH with gun after perforating. Note rate of / surface pressure build for 5 minutes. Then open w~. ck up to flow while POOH with spent gun and RIH with new gun. /- ) g. ;~::~r~~s=d ;~~:~nd log. Perforate ~';:~~~' KB while monitoring h. MU CCL and 15' 3.375" aD, 6 8PF perforating gun loaded 13' with 3 1/8", 8DP-3125-311NT3 charges. Maximum gun s.well in ~!"is 3.635" O.D. with .// an average entrance hole of 0.36" and penetratIon 9f40.~5". i. Correlate to cased hole bond log. Perforate 640Yto.~;.I-'18' while monitoring surface pressure. POOH. L-::::;~," j. RDMO Expro. /' 2) Flow well to production facility. ''N\ MARATHON ) Marathon Oil Company ) Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 May 18,2004 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Att~elíêd)nd submitted for your approval is the Form 10-403 to perforate additional /' l1on/ek/gas pay in the Falls Creek #1 RD wellbore. This well is an active Tyonek gas prõêucer. Also attached for your records is the well schematic, and proposed operational procedure. If you would like any other information, please contact me at 283- 1311 or kdwalsh@marathonoil.com. Sincerely, \~ b. tAJ~ Ken D. Walsh Advanced Production Engineer Enclosures RECEIVED MAY 2 8 2004 Alaska Oil & Gas Cons. Ctjrni1\::~:;~:¡û¡; AnchoragE! OR\G,NA;.. W (-ri~' 0/5 lP/¡ /2-004. (,I/ I 9- ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 9. Well name and number: Falls Creek #1 RD / 10. Field/Pools(s): \LJ6A ) r _WHdc~ F a..ì (Ç. CV €ß- K... / T ~~ CYLe¥_ U tIl.(ttl PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 8468' 10,597' 8397' Length Size MD 28' 36" 28' 248' 20" 248' 2468' 13-3/8" 2468' 3133' 9-5/8" 3133' 8900' 4/1/2" 8900' 12. Attachments: Description Summary of Proposal I Detailed Operations Program IÐ BOP Sketch --' Wellbore Diagram [Xl 14. Estimated Date for Commencing Operations: 6/10/2004 / 16. Verbal Approval Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Type of Request: Abandon D Suspend Well D Alter Casing D Repair Well D Change Approved Program D Pull TubingD 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 196168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 276' 8. Property Designation: Falls Creek PA (ADL 590) 11. Total Depth MD (ft.) 10668' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7403-7423' /7335-7367' Packers and SSSV Type: N/A Perforation Depth TVD (ft): 6825-6845' /6757-6789' Date: Printed Name Signature K"[t:b. W~ Operation Shutdown D Perforate [R] varianceD Annular DisposalD Plug perforationsD StimulateD Time ExtensionD OtherD Perforate New Pool D Re-enter Suspended Well D 4. Current Well C~ vJ6~ 5. Permit to Drill ,Number: Development _ Explorat~ 201-155 / Stratigraphic Service 6. API Number: / 50- 133-10005-01 GfL~ Plug (measured): Junk (measured): TVD 28' 248' 2440' 3071' 8322' Burst Collapse N/A N/A 2260 psi 3090 psi 7500 psi N/A N/A 5020 psi 5750 psi 8430 psi Tubing Size: N/A Tubing Grade: N/A Packers and SSSV MD (ft): N/A 13. Well Class after proposed work: W 6~ ExPloratOry-8" Development L.!J Tubing MD (ft.): N/A Service D 15. Well Status after propose~ork: Oil D Gas~ / PluggedD Abandoned D WAG D GINJD WDSPL D WINJD Contact Ken D. Walsh 907-394-3060 Title Advanced Production Engineer Phone 907-394-3060 Date 5/18/2004 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test D Mechanical Integrity Test D Other: "Te sd- 1$0 p f 1-0 '5 <.,')0 0 (J S í' . 10 --.4Q4 I , ',-, ..,.:., -' J ~ '"...J, .J;";~:;') Subsequent Form Requested: Approved by: Form 1 0-403 Revised 2/2003 304· ~óL/ Location Clearance ~E.CE.\\IE.O W\~'< ~ ~ l~~~ . .. \:.omfíÙSS\on BY ORDER OF þ.\as\<.a 0\\ !Ii GaS ~~:;~ /" II I / I COMMISSIONER THE COMMISSION Date,Þ.nC WI IjÓ If JUM 0 ~~, ?pn~ t, Sub~it in duplicate ORIGINAL ØSDMSBFl ) ) M MARATHON f MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Falls Creek #1 rd Perforate Additional Pay WBS# 05/18/2004 Objective: Perforate additional Tyonek zones (7403-7423' (Class 2) and 7335-7367' (Class 1). 1) MIRU Expro perforators. a. Hold PJSM. , b. Install BOPE with pump in sub to 4 1/8" 5K tree. ~// c. Install sufficient lubricator for 20' of3.375" p"erforating guns. d. Test BOPE and lubricator to 250/3000 psi. / e. ND lubricator and MU perforating gun f. MU CCL 20' 3.375" OD, 6 spf loaded with 3 1/8", SDP-3125-311NT3 charges. Maximum gun swell in air is 3.635" O.D. with an average entrance hole of 0.36" and penetration of 40.25". g. Correlate to cased hole bond log. Shoot from 7,403' to 7,423' KB while / monitoring surface pressure. POOH. h. MU CCL 20' 3.375" OD, 6 spf with .36" hole and 40.25" penetration. /' Correlate to cased hole bond log. Shoot from 7,347' to 7,367' while monitoring surface pressure. POOH. i. MU CCL 12' 3.375" OD, 6 spf with .36" hole and 40.25" penetration. " Correlate to cased hole bond log. Shoot from 7,335' to 7,347' while / monitoring surface pressure. POOH. j. RDMO Expro. 2) Flow well to production facility. ¡~~ ¡; ~ ¡"iI, ,r~ :~ ;~>3 ~! fì! h! fi¡" ~. 1'1,' iï. ~~ i!~ ','..i ;J. ~':t ~~~"~,~ ~:~~ ~;- "~ ~.~ I~ Ghemicallnjection ~~', ¡:~ Mandrel @ 2000' ,)~ I f'\: :~~ ¡~ ~; ~ ;1 j,'~ ~ :r~~.. 1'Ji.~ '! ~Ip I!i ::;~ ~ ~~IS)~ I'~,. ;¡;.'J'f)f f~ ;¡,i ~:: , f'alls Creek #1 RD Sidetrack 4 1/2", 12,6 ppf, L-80 Modified Buttress in 6 3/4" Hole ) f:~ :~ IS!! tl,'" '1iII','·" <.j, t ~.!" ,,~ i.·I~ ~'1. . ~:' ; ~I":". '~ ~~, S)~ 11: I¡~ ~~' ;AI f . ¡11¡ ~~ 1""1 !;~ ~ ~,~ ~, :"~~. ~,~ ~ ~.~ t}! ,,: ",,.j ~",j¡j~ 17' 'I'" ;;:~ ~ ,~);~ ;¡. i~~ ~I,- ~é ~~ :~ )iI,; ~ ~ ~~ ~ " !,ot ¡, ¡. ~ ~j ~~ !':r~ ~-II" ,~ ~ ." :~:\ ',~I': "," I" '.'~ ~I (..:: ,~ l iJ 'J' '.'" ~, 41; ~. t~,; ;.¡ ); ; ;, ~, ~ !¥1 ~ \., ~:~ ..;. .il';',:';' ~ ~I" ,r .. ',01 S. :tì ~; .:.. ¡.;. :::I = :II - t¡ \i;' ~..:. ~-.. ~ )I; ""- ¡, :::I: II: ::II: C ) :'r'~ r~l~ ~QJ :~4:~ lI.t I\í.~: 1~ .ât .~~ ~'<~,,~ ~..¡; .J M MARATHOI TOG 2650' 4 1/2" X Nipple (3.813" 10) @ 5387' MO Proposed Perfs: 7335'-7347' 7347'-7367' 7403'-7423' Tvonek Perfs: 7914'-7934' MD 2-3/8", 60 deg, 8spf 1/4/04 Tyonek T -3 Perforations: 8714' - 8750' MO 2-7/8" PJ 29066 spf ~ ~ ~ ~ 8809' MD PBTO :¡g1~ TO: 8900'MD/8322'TVO ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC Addperfs Sundry.XL$ W6^ 1¿12.~ 2-ðOS I)?, /î' 12-{ 2:3 r 3 ¿~-4 . -;> f_ ", {/, Ü (eft c! Suspend Repair Well Pull Tubing 5. Type of Well: Development Exploratory ~ Stratigraphic Service 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1898' FSL & 2885' FEL, sec. 6, T1N, R12W, SM At top of Productive Interval 1821' FSL & 5013' FEL, sec. 6, T1N, R12W, SM At Effective Depth Operation Shutdown Plugging Variance Add Perforations At Total Depth 1830', FSL, & 2025' FEL, sec. 6, T 1N, R12W, SM 12. Present Well Condition Summary Total Depth: measured true vertical 8900 8322 Effective Depth: measured true vertical 8851 8273 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size 28' 36" 248' 20" 2468' 13-3/8" 3150' 9-5/8" 8900' 4-1/2" Present 8714'-8750' 6spf true vertical Present 8136'-8172' 6spf Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) N/A 13. Attachments Description Summary of Proposal 14. Estimated Date for Commencing Operation 12/26/2003 16. If Proposal was Verbally Approved feet feet Plugs (measured) feet feet Junk (measured) Cemented Driven 480 sx 1660 sx 1884 sx 1052 sx Measured Depth 28' 248' 2468' 3150' 8900' Proposed 7,914 . 7,934, 8 spf Proposed 7,336'· 7,356' 8 spf Re-enter Suspended Well Time Extension Stimulate Perforate X Other 6. Datum Elevation (OF or KB) '21.5' DF-GL 7. Unit or Property Name Falls Creek Unit 8. Well Number FC #1rd /1 9. Permit Numbey 201-155 10. API Number 50-- 133-10005-01 / 11. Field/Pool Falls Creek / Tyonek feet True Vertical Depth 28' 248' 2440' 8327' 8322' RECEIVED DEC 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage 15. Status of Well Classification as: Detailed Operations Program ~ BOP Sketch Oil Gas X ¡¿ Il3/lc.ø~ Name of Approver v.4 (¡ t\- Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~'\.. ~l ~.U"¿'''---Donald Eynon Title Production Engineer / FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 1 0- - é.f. 0 i./- I~ ~fl DEÇ .2 ';j 1m3 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Origina1 Signed By Sa,.g, Põ R \ G \ N A L Suspended Date 12/19/2003 Approval No. <- ~cL3- 386 Commissioner Daæ L~~n~~,~ate ) ) Marathon Oil Company Alaska Region FC #lrd Ninilchik Gas Field, FC Pad Add Perforations Procedure WBS # WO.03.09933.EXP History: FC lrd is cemented 4-1/2" production pipe run to 8,900'. Additional pay has been identified in the wellbore. Objective: Perforate additional pay. Procedure: 1. Ensure location and tree are prepped for wire line including liner installation and house removal if necessary. 2. MIRV wire line unit. 3. Perforate as follows with 2-3/8" 4SPF, retrievable gun, 7914'-7934'(20'). POOH. MU second 20' 2 3/8" 4spf gun and shoot same interval 7914' - 7,934' (20'). 4. Clean up location. RDMO e-line, and return well to system per instruction of production engineer. Flowback to open top tank if necessary. ) Falls Creek #1 RD Sidetrack I Chemical Injection Mandrel @ 2000' Whipstock @ 3133' CIBP @ +/- 3151' (WLM) Cement Retainer @ 3850' Cement Plug: 3850'-4011 ' Cement Retainer @ 5225' Cement Plug: 5200'-5991' Baker Model D @ 7545' ~ ..; . J. ~~ "',,~ ~ 'l ~. Cem;nt PI~g: ~1.1. .. t. ....~~.~: 7562-7641 ~~ "~.~~.....~ . !:- -.µ . ~. . ~f1r~~ 27/8", 6.5ppf, N-80 8rd@ 7641' ~~~'. ¡ ~~ "~~ !'Ift..::.;¡ Original Perfs: ~\~~ ¡ ~~!! 3900'-3911' ~ ", . .::.;~ 5290'-5315' ~ ~ 5442'-54 70' ~~ ~~ ),t )'" 7562'-7600'. IÏ Sqz Holes: 3884'-3886' 5275',5326', 5419', 5490' 7550', 7615' I'·..t!..'.···.·..·.···.··.'·.··....'..'.... / \; "- J TOC 2650' . , M MARATHON t·, .. 4 1/2", 12.6 ppf, L-80 ~ Modified Buttress in 6 3/4" Hole I~ ~~ ~.~ :¡;! I I I 4 1/2" X Nipple (3.813" ID) @ 5387' MD I ~ !~ ~~ !~ I ~ I Wi ,~ Yi I -TI< ~ ~ it; ,p. ~ II ~, I ~. I , I ~ I ~~ W , ~~ ~ ~. Il' ~!f ~~ ....1 =:I ::s:: .. L J:: !::: Tvonek T -3 Perforations: 8714' - 8750' MD 2-7/8" PJ 29066 spf ;; I' ~ i i, ~ 8809' MD PBTD ~~~8900.MD/8322'TVD ~ ) ') Alaska Business Unit Domestic Production " , M MARATHON 4 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 19, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: FC #1 rd Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals for NGF well FC #1 rd. The proposed work is to add perforations to other identified pay in the well bore. / This work is expected to begin Friday, December 26. I have enclosed a procedure and a wellbore diagram for your review. If you need any additional information, I can be reached at 907-283-1333 or bye-mail atdmtitus@marathonoil.com. SincrrelY, '~~ \ \l- r1J!fl(j~' Denise M. Titus Production Engineer Enclosures RECEIVED DEC 2 2 2003 A'aska ai' & Gas Cons. Commission Anchorage ORIGINAL ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC A.ddPerfS SundryXLS ./ kJG A ¡ L./ -z.:L 2...00"~ PIS (2./l2/3 Suspend Repair Well Pull Tubing 5. Type of Well: Development _ Exploratory ~ Stratigraphic Service 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1898' FSL & 2885' FEL, sec. 6, T1N, R12W, SM At top of Productive Interval 1821' FSL & 5013' FEL, sec. 6, T1N, R12W, SM At Effective Depth At Total Depth 1830', FSL, & 2025' FEL, sec. 6, T 1N, R12W, SM 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 28' 248' 2468' 3150' 8900' measured 8714'·8750' 6spf true vertical 8136'·8172' 6spf Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description Summary of Proposal 14. Estimated Date for Commencing Operation 12/26/2003 16. If Proposal was Verbally Approved Operation Shutdown Plugging Variance Add Perforations 8900 8322 8851 8273 Size 36" 20" 13-3/8" 9-5/8" 4-1/2" N/A N/A feet feet Plugs (measured) Re-enter Suspended Well Time Extension Stimulate Perforate X Other 6. Datum Elevation (DF or KB) '21.5' DF-GL 7. Unit or Property Name Falls Creek Unit 8. Well Number FC #1rd /" 9. Permit Number 201-155 / 10. API Number /' 50-- 133-10005-01 11. Field/Pool Falls Creek / Tyonek feet feet feet Junk (measured) True Vertical Depth 28' 248' 2440' 8327' 8322' RECEIVED DEC 2 2 2003 Alaska Oil & Gas Cons. Commission Anchorage 15. Status of Well Classification as: Detailed Operations Program ..!... BOP Sketch Suspended Date 12/19/2003 Approval No. 303-38'"3 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 " ,-!-O '-I- . 0"t:~~:' Ò RIG I N A L Commissioner Date~~L2fJf Cemented Driven 480 sx 1660 sx 1884 sx 1 052 sx Measured Depth 28' 248' 2468' 3150' 8900' Name of Approver Date Approved Service 17. I hereby œrt~ tha: the; A~Oing is tr e and correct to the best of my knowledge. Signed ~ J V ) Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Rec¡,uired 10- - 4' 04- S pe.~k'( o...e.,tLt.«.. T P ~TÎo (' /-"Lte-d ¡'i'\.. r-ervc,-( ~ I (j Br¡¡~ 8ft DEe 22 a~ Oil Gas X , , M MARATHON ~ ) ') Marathon Oil Company Alaska Region FC #1 rd Ninilchik Gas Field, FC Pad Add Perforations Procedure WBS# History: FC 1rd is cemented 4-1/2" production pipe run to. Additional pay has been identified in the wellbore. Objective: Perforate additional pay. Procedure: 1. Ensure location and tree are prepped for wire line including liner installation and house removal if necessary. 2. MIRV wire line unit. 3. Perforate as follows with 2-3/8" 4SP~evable guns: 7910'-7935' ~ 4. Clean up location. RDMO eline, and return well to system per instruction of production engineer. Flowback to open top tank if necessary. ) ~'I:,ffj- !":,,L :,'.,,:'4 4 ~ ~ :,4 ~~ ~ t:.!! !\,o ~" !'i." '. '.,' \"," ~:,:~1, ,: ~~~ ~ :t) A- Chemical Injection ~ ~~ ~ Mandrel @ 2000' ¡~n ~:'ì~4: I~ :~~ hiJ ,~ ;r~ ¡~;'" ~ ~. .·..ê ", ~. i:) ii" -.,...: ~4"'. CIBP @ +1- 3151' (WLM) 'ot ~~ ~~~" '-o!";JI,', ~ Cement Retainer @ 3850' ;~ Falls Creek #1 RD Sidetrack Whipstock @ 3133' Cement Plug: 3850'-4011 ' Cement Retainer @ 5225' Cement Plug: 5200'-5991 ' Baker Model 0 @ 7545' Cement Plug: 7562'-7641' 27/8", 6.5ppf, N-80 8rd @ 7641' Original Perfs: 3900'-3911 ' 5290'-5315' 5442'-5470' 7562'-7600' Sqz Holes: 3884'-3886' 5275', 5326' 5419', 5490' 7550', 7615' :;,1, ~,,~,,~ :'r;.d .~ ¡'"~ ~: ;; ~....' ~": þ . ".;; !~ ~¡'~1 ~ ~;tl' ... ~"",' 4!'~ :' ~;;. . ·1'~"1'¡ !t"" f. ¡~,~ ;¿ ~..~; ~~ ~,~ ~~ ,~ .~;, ~.~" ) -!~~ !II'~ â M MAlA THO. TOC 2650' <~,~ ~ ." \ifl "'. :¡. 101 ',. u ~ ;;: ~ \II; ~,' ii' ..' ) , . t.. 'It ¡. , ~ ~~~ · 4 1/2" X Nipple (3.813" 10) @ 5387' MO ~ ",'" '4 ~'.. ~~ ,. ~; ) ) " t:: . " :" '1' ¡, :... ~ ! I' ~..' 'I" ~ .l Z ,. =- = "P' It""' ... " r ~ rI ~; ~ '. ''"'. !,.- ~,,; ...:¿ ~ ::::I z:: ::::!: ~ Proposed Add Perforations: 7910'-7~¡ Tvonek T -3 Perforations: 8714' - 8750' MD 2-7/8" PJ 2906 6 spf -:; I' ~ ~ ~r ~~r' 8809' MO PBTD . ' t~~~~\; TO: 8900'MO/8322'TVO T" .' ..:.r t... } ¡..It )1.,) ¡í.:.>t C::( FRANK H. MURKOWSKl, GOVERNOR -. ,-- -. ..", '.. . DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL #700208600003 35387853 RETURN RECEIPT REQUESTED Mr. J. Brock Riddle Land Manager Marathon Oil Company P.Ò. Box 196168 i\nchorage,AJ( 99519-6168 June 19, 2003 RECEIVED .¡,"I DECISION OF THE DIRECTOR JUN 2 3 2003 Alaska Oil & Gas Cons. Commission Subject: Request for extended confidentiality under lIAAC83.153, Anchorage ~~\-/~-)Marathon Falls Creek 1RD, API 501331000501; ~()'O - o&~Marathon Grassim Oskolkoff 1, API 501332049300; "'-01- 0 q~ Marathon Grassim Oskolkoff 2, API 501332050300; l.rf- :zo8 Marathon Susan Dionne 1, API 501331000201 (only data and documents dated September 1, 2001 and later); ~o;.- o7ð Marathon Susan Dionne 3, API 501332051200. Mr. Riddle: I am responding to your February 4,2003, letter to me in which you request extended confidentiality under 11 AAC 83.153 for certain information derived from the five. above-referenced wells. On April 17, 2003, Marathon Oil Company (Marathon) provided the Division of Oil and Gas (Division) with documents supporting its position that all of the above referenced wells are within three miles of unleased tracts and that the information derived from the wells is significant information relating to the valuation of those unleased tracts. After considering the information available to the Division, the confidentiality period for infoTI11ation derived from the five above-referenced wells is extended for two years from this date, June 19,2003, through June 19, 2005, or 90 days after leases are granted or issued for the unleased lands identified by Marathon at the time of this request, whichever occurs earlier, unless Marathon gives written permission to release the information at an earlier date. On June 20, 2005, information on all of the wells will be released to the public unless Marathon requests and the Division grants another extension under 11 AAC 83.153. Marathon shall make any request on or before May 15,2005, to allow the Division to make a decision by June 19,2005, regarding further extension of the confidentiality period. "Develop, COllserve, and Enhance Natural Resollrces for Present and Future Alaskans." ; .... ) ) By copy of this letter I am notifying the Alaska Oil and Gas Conservation Commission (AOGCC) of the extension of confidentiality for the five above-referenced wells. For the Marathon Susan Dionne 1, API 501331000201, only data and documents received by the AOGCC on or after June 1,2001, are subj ect to extended confidentiality. All data and documents from Marathon Susan Dionne 1 (previously known as the Alaska Crude Corp. McCoy Prospect 1), API 501331000201, received before June 1, 2001, are to remain available to the p1;1plic. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. ih Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals@dnr.state.ak.us. This decision takes effect immediately. An eligible person must first appeal this decision in accordance wHh 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, ~ 0 ~¿{Y Mark D. Myers Director ~ Cc: Sarah H Palin, Commission Chair, AOGCC Jeff Landry, Department of Law J. R. Cowan, Division of Oil and Gas ) MEMORANDUM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Files FROM: Jody COlombierY./ Special Staff A+ DATE: June 19,2003 SUBJECT: Extended Confidentiality Maps The backup maps for Marathons Request for Data Confidentiality Extensions and DNR Decision of the Director are located in 201-155 Falls Creek1 RD 200-82 201-96 185-208 202-70 Grassim Osko1koff 1 Grassim Osko1koff 2 Susan Dionne 1 Susan Dionne 3 ) Alaska l )ness Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 4,2003 Mr. Mark Myers, Director Alaska Department of Natural Resources Oil and Gas Division 550 West ih Ave., Suite 800 Anchorage, AK 99501 VIA CERTIFIED MAIL RE: Request for Data Confidentiality Extension Marathon Falls Creek lRD, Sec. 6-TIN-RI2W, API 501331000501 Marathon Grassim Oskolkoff 1, Sec. 23-TIN-RI3W, API 501332049300 Marathon Grassim Oskolkoff2, Sec. 23-TIN-RI3W, API 501332050300 Marathon Susan Dionne 1, Sec. 6-TIS-RI3W, API 501331000200 Marathon Susan Dionne 3, Sec. 6-TIS-RI3W, API 501332051200 Dear Mr. Myers: This letter is to request that DNR extend the confidentiality protection of 11 AAC 83.153(a) to all well data and reports concerning the above-mentioned wells. Such approval also will extend the confidentiality period for the above wells beyond the 24 months prescribed under the AOGCC's regulations. 20 AAC 25.537(d). Upon written request, 11 AAC 83.153(a) authorizes DNR to extend the confidentiality of required well reports "contain[ing] significant information relating to the valuation of unleased land within a three-mile radius of the well from which these reports or information were obtained." The attached Exhibit A and plat (Exhibit B) identify unleased lands that lie within three miles of the above wells and are in the Ninilchik Exploration Unit. As I am certain you recognize, Marathon's reports concerning the above wells contain information substantially bearing on the valuation of these lands. Accordingly, extension of the confidentiality protections of 11 AAC 83.153 is appropriate. Marathon requests that the confidentiality of the information be extended until such time that these lands are leased. Upon your approval of this request, please notify the Alaska Oil and Gas Conservation Commission of your finding that Marathon's reports "contain significant information relating to the valuation of unleased land in the same vicinity," within the meaning of 11 AAC 83.153(a) and 20 AAC 25.537(d), and verifying DNR's extension of the confidentiality of Marathon's well data. Please contact me directly if you have any questions regarding the information provided in connection with this request or would like to discuss Marathon's request further. cc: Cammy Taylor, AOGCC Certified Receipt: 70020510000311101235 Attachments Environmentally aware for the long run. I~ FALL~ CREEK l1NI:~_I -i-' ___+ ! :! ~. Irr$j,f~~i~banlt) I r--¡ ~. / :HBP : I: 0 ;,; 1'1. rí~ ~~~~E~~:lde"bilt) I tr...........I I 'T ,., -, HBP , I I. 1 ";~tAI 'I @) ,I ~'\ ~(H.A. Pederson) f r-....-r.. MOC-EtAI I. j}. .~ ~l)'LU .. ""J!J?!" I.. :- I' I ADL-Ó0590 t '. .~~ _ M~C-EtAI .} , Í'..... HBP""- 3~ ¡~~~.~.'.. ", (M.~. Stark) · ~ I: ~.... f...·.' (:~j \'HBP ...' ~ + _ _:' ~._ _ __..... -~- __...,.,,\;,1' .:..~."- . "1 .......' ...-- -- ---. -A.d. "MOC-EtAI ~3': r ' J ;II' A -024399 ...:...... .... .. , ~ · . LHBP (L.Eaiand)! SHL. 1896' FSL & 2395' FWL J ..~""""""'.-P"_.-'!i (. '" SectIon 6 -IN -12W, 8M t , . I I tt7 . I . t I I ¡ 1 BHL 1896' FSL & 367' FWL I · I Section 6 -IN -12W, 8M; I'" . t I Nap I t I . 1 ! I - - - - - --+----- ---.... -----+- -- ,!.~- -------- - -.--+ t I f ,I F J J J I J I ~ t f . ~ I J ~ t . '4' t, f: tt I · ~ J I ; ~ t I (\...£""41 I , .~OZ.3" t I f fiBI' "! , " t J I . 1 I", ,;,..,---....-4- ---~ t.- -- _... _...._.~.......;.... -..... -.- -- --- --+ 1: 'N., RJ3 w: ~. I IN.,ftI2 W. , ; 2! ¡.. +--------------+--~--- , f , , t I I I I I I I 1 f I I I , t f , , , , t -t- - -- - - - - - - - - - - -- I I , I , 1 I I I I I I ~ 3 ; ~ '!o.. ~" It AOL oo~.,o ~ 1 Mile :: ~- \. , ,,, EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE 23A NINILCHIK UNIT UNLEASED ACREAGE - FEDERAL, STATE AND CIRI ACREAGE 1f~;;~Qj fJ5fgR'~ffft~Ð.pjlli~e_,Ed.~~_Jaìîø:~@iVp:~_~~¡~Ž~$Î~~~i~~ijlÜ,~$~W~r\~£~~~';~4~~ Uncommitted 12 13 17 TOTAL: T 2N - R 12W 220.0000 Section 21: S/2NE/4 & SE/4NW/4 & NE/4SW/4 & NW /4SE/4 & W/2E/2SE/4 & SE/4NE/4SE/4 &S/2NE/4NE/4SE/4 lying northwesterly of and including the Sterling Highway (estimated at 220 acres) T 1 N - R 12W 59.9600 Section 5: Lot 3 & E/2SE/4NW/4 T 1 N - R 12W 40.0000 Section 7: SE/4NW/4 T 1N - R 13W 120.0000 Section 34: NW/4SW/4 & S/2NW/4 Cook Inlet Region, Inc. 100% (Note - Patent to CIRI in process) '-"'. State of Alaska Uncommitted . State of Alaska Uncommitted U.S.A. Uncommitted 439.9600 .-' Page 1 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE NINILCHIK UNIT UNLEASED ACREAGE - PATENTED FEE ACREAGE f~:: 33A-1 T 2N - R 12W 2.8520 Marshall K. Coryell 1/5 Uncommitted Section 21: Lots 3-5, Block 1 & (subject to nonparticipating royalties - Lots 2,3,5,7 & 8 of Block 2 and same owners as Tract #32) all the dedicated streets of Clam Gulch Acres Subdivision, plat #86-81 and the unsubdivided remainder of the SW 14SE/4 lying Southeast of the Sterling Highway 33A T 2N - R 12W 0.4000 Jeff L. & Hilda G. Wells 1/5 Uncommitted "-" Section 21: Lots 1 & 2, Block 1 (subject to nonparticipating royalties - Clam Gulch Acres Subdivision, same owners as Tract #32) plat #86-81 33C T 2N - R 12W 3.6900 Kelly Guy Baker Uncommitted Section 21: Lots 6, 9, 10, Block (subject to nonparticipating royalties - 2 of Clam Gulch Acres same owners as Tract #32) Subdivision, plat #86-81 33D T 2N - R 12W 7.8400 Nell Kelly Uncommitted Section 21: The minerals (subject to nonparticipating royalties - underlying the right of way of same owners as Tract #32) the Sterling Highway as it crosses the SW/4SE/4 (est. 7.84 acres) 33E T 2N - R 12W 1.0000 Delphine L. Chasing-Hawk Uncommitted Section 21: Lot 1, Block 2 of (subject to nonparticipating royalties - Clam Gulch Acres Subdivision, same owners as Tract #32) plat #86-81 33F T 2N - R 12W 1 .1 000 Robert E. Link & Deborah A. Link Uncommitted Section 21: Lot 4, Block 2 of (H&W) - Clam Gulch Acres Subdivision, (subject to nonparticipating royalties - plat #86-81 same owners as Tract #32) 38 T 2N - R 12W 22.1175 Marguerite Hawkins 5% Uncommitted Section 29: Lots 2 & 3 & James Hawkins 5% N/2SE/4 less a tract in the Ian Hawkins, deceased 5% Northeastern corner of the N/2SE/4 owned by Vernon Andrews and Leonard Keener (excluded tract is Tract #39 of this exhibit) Page 2 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 1.9550 Theodore L. & Ann C. Morris 25% Uncommitted Section29: Block 7 of Clam Thomas W. Patmor 25% Gulch Park, Plat #75-69 42A T 2N - R 12W 2.7940 Ronald E. Russell 100% Uncommitted Section 32: Tract G of Clam Gulch Subdivision Osmar 1981 Addition, Plat #81-51 43 T 2N - R 12W 2.1800 Shirley Ann Grow & Richard James Uncommitted Section 32: Lot 2, Clam Gulch Edelman 100% Subdivision, Plat #90-18 44B-1 T 2N - R 12W 0.5000 Walter & Edna Wilson 50% Uncommitted '~ Section 32: Lot 12, Thomack Subdivision, Plat #K-1575, in so far as it lies within Tract "A" of former plat #K-509 (est. 1.0 acre) 44B-2 T2N-R12W 0.2150 Walter & Edna Wilson 50% Uncommitted Section 32: Lot 12, Thomack Subdivision, Plat #K-1575, in so far as it lies outsideTract "A" of former plat #K-509 (est. 0.43 acre) 44C-1 T 2N - R 12W 0.3575 John T. Givens 50% Uncommitted Section 32: Lot 13, Thomack Subdivision, Plat #K-1575 in so far as it lies within Tract "A" of former plat #K-509 (est. 0.715 acre) 44C-2 T 2N - R 12W 0.3575 John T. Givens 50% Uncommitted Section 32: Lot 13, Thomack ~ Subdivision, Plat #K-1575 in so far as it lies outside Tract "A" of former plat #K-509 (est. 0.715 acre) 44E T 2N - R 12W 0.7100 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lot15, Thomack Subdivision, Plat #K-1575 Page 3 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 1 .2650 Dolores C. Sage 50% Uncommitted Section 32:Lot C-1, Thomack Subdivision, Plat #K-1575 & Lot 1, Clam Gulch Subdivision, Conley 1977 Addition & also Lot 1 of Plat #78-43 44H T 2N - R 12W 1.3200 Jennifer Abbott 100% Uncommitted Section 32: Lot 2 of Clam Gulch Subdivision, Conley 1977 Addition, plat #78-43 44J T 2N - R 12W 1 .2300 Peter J. & Carolyn J. Crosby 100% Uncommitted "'- Section 32: Lot 4 of Clam Gulch Subdivision, Conley 1977 Addition, plat #78-43 44K T 2N - R 12W 1.2900 Brian J. Farney 100% Uncommitted Section 32: Lot 5 of Clam Gulch Subdivision, Conley 1977 Addition, plat #78-43 44L T 2N - R 12W 5.2300 James R. Sabrowski 1/2 Uncommitted Section 32: A 5.23 acres tract Leonard & Juanita Sabrowski described by metes and Revocable Living Trust 1/2 bounds and lying within Clam Gulch Subdivision (See legal description at end of report) 44M T 2N - R 12W 0.1900 Theodore L. & Ann C. Morris 50% Uncommitted Section 32: Tract F of Clam Gulch Subdivision, Morris 1979 Addition. plat #79-192 44N T 2N - R 12W 0.4600 Edna Fuller 50% Uncommitted " '-" Section 32: Lots 1-3 & 1-4 of Clam Gulch Subdivision, Morris 1979 Addition, Plat #79- . -~ 44P T 2N - R 12W 0.2750 Earl Carmichael 50% Uncommitted Section 32: Lot 1-8-2 of Clam Gulch Subdivision Morris 1979 Addition, plat #79-192 44Q T 2N - R 12W 0.2600 Theodore L. Morris & Ann C. Morris Uncommitted Section 32: Lot 1-B-1 of Clam 25% Gulch Subdivision, Morris 1979 Karl & Marina Lauterbach 25% Addition, Plat #79-192 Page 4 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 0.4000 Terry A. & Theresa A. Ellis 100% Uncommitted Section 32: Triangular portion of Lot 3, Clam Gulch Subdivision, Plat #90-28 44S T 2N - R 12W 0.6800 Barbara A. Minich 100% Uncommitted Section 32: A 150' x 200' Tract in the N/2 of Lot 3 of Clam Gulch Subdivision, plat #90-28 44T T 2N - R 12W 0.2500 Ronald E. & Audrey L. Russell 1 00% Uncommitted Section 32: The southeast 138.9' of Lot 3 of Clam Gulch '-' Subdivision, plat #90-28 44U T 2N - R 12W 1.0000 Lue Rae Erickson 100% Uncommitted Section 32: Lot 4 & Lot 15, Clam Gulch subdivision, plat #90-28 44V T 2N - R 12W 0.4000 Susan R. Cange 100% Uncommitted Section 32: Lot 5, Clam Gulch Subdivision, plat #90-28 44W T 2N - R 12W 0.8000 Ronald E. Russell 100% Uncommitted Section 32: Lots 6 & 7, Clam Gulch Subdivision, plat #90-28 44X T 2N - R 12W 0.8000 John J. & Emily J. Minnick Uncommitted Section 32: Lots 8 & 9, Clam Gulch Subdivision, plat #90-28 44AA T 2N - R 12W 0.8000 Deborah Lee Murphy 100% Uncommitted Section 32: Lot 13A, Clam Gulch Subdivision, plat #90-28 : 44AE T 2N - R 12W 2.0100 Arlyn H. & June C. Thomack 50% Uncommitted -' Section 32: Lots 1 A & 10A, Clam Gulch Subdivision No.2, Plat #95-58 & minerals under the roadbeds of Thomack Street and North Laurel 44AF T 2N - R 12W 0.3800 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lots 8 & 9, Thomack Subdivision, Plat #K- 1575 Page 5 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 0.2950 Sharon Nahomey 50% Uncommitted Section 32: Lot 7, Thomack Subdivision, Plat #K-1575 44AH-3 T2N-R12W 0.0685 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lots 5 & 6, Thomack Subdivision, Plat #K- 1575 in so far as it lies within Tract "A" of former plat #K-509 (est. 0.137 acre) 44AH-4 T 2N - R 12W 0.1186 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lots 5 & 6, -- Thomack Subdivision, Plat #K- 1575 in so far as it lies outside Tract "A" of former plat #K-509 (est. 0.2372 acre) 44AI T 2N - R 12W 1.5150 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lot C-10 of Thomack Subd., Plat #1502 44AJ T 2N - R 12W 0.1400 Arlyn H. & June C. Thomack 50% Uncommitted Section 32: Lot 3, Thomack Subdivision, Plat #K-1575 44AL T 2N - R 12W 0.5000 Janet & Ronald Brackett 50% Uncommitted Section 32: Block 6, Clam Gulch Park Subdivision, plat #75-69 45A T 2N - R 12W 0.3150 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 10, Block 5, Michael F. Harrigan 12.5% Clam Gulch Park Subdivision 45B T 2N - R 12W 0.2500 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 9, Block 5, Phyllis Edwards 12.5% ~ Clam Gulch Park Subdivision, plat #75-69 45C T 2N - R 12W 0.1725 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 8, Block 5, Clam Gulch Park Subdivision, plat #75-69 450 T 2N - R 12W 0.1725 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 7, Block 5, Clam Gulch Park Subdivision, plat #75-69 Page 6 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 0.1916 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 6, Block 5, Jack Boughton 1/3 x 12.5% Clam Gulch Park Subdivision, plat #75-69 45F T 2N - R 12W 0.4600 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 4 & 5, Block 5, Sherwood Williams, Jr. & Darlene M. Clam Gulch Park Subdivision, Ross 12.5% plat #75-69 45G T 2N - R 12W 0.1725 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 3, Block 5, Clam Gulch Park Subdivision, -- plat #75-69 45H T 2N - R 12W 0.2400 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 1, Block 5, Danny C. & Alice Eileen Rose 12.5% Clam Gulch Park Subdivision, plat #75-69 451 T 2N - R 12W 0.2150 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 2, Block 5, Robert W. & Casina G. Wilkins 12.5% Clam Gulch Park Subdivision, plat #75-69 45J T 2N - R 12W 0.4125 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 1 & 2, Block 1, Clam Gulch Park Subdivision, plat #75-69 45K T 2N - R 12W 0.6650 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 1,2, 3, Block Mildred A. Drum 12.5% 2, Clam Gulch Park Subdivision, plat #75-69 45L T2N-R12W 0.4600 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 4 & 5, Block 2, William L. & Renae Denton 12.5% ~' Clam Gulch Park Subdivision, plat #75-69 45M T 2N - R 12W 0.4600 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 6 & 7, Block 2, Kurt Neil & Vicki L. Nelson 12.5% Clam Gulch Park Subdivision, plat #75-69 45N T2N-R12W 1 .1500 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 8,9,10 & 11, Charles R. & Elizabeth J. Hudson Block 2, Clam Gulch Park 12.5% Subdivision. olat #75-69 Page 7 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 0.4850 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 1 & 2, Block 4, Jerome O. Thorne & Theresa Snow Clam Gulch Park Subdivision, 12.5% plat #75-69 45P T 2N - R 12W 0.1725 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 3, Block 4, Clam Gulch Park Subdivision, plat #75-69 45Q T 2N - R 12W 0.2300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 4, Block 4, John W. & Marjorie L. Williamson Clam Gulch Park Subdivision, 12.5% plat #75-69 \~ 45R T 2N - R 12W 0.2300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 5, Block 4, Jean M. & Larry P. Brooking 12.5% Clam Gulch Park Subdivision, plat #75-69 45S T 2N - R 12W 0.1725 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 6, Block 4, Clam Gulch Park Subdivision, plat #75-69 45T T 2N - R 12W 0.2300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 7, Block 4, Lee F. & Alice M. Hawkins 12.5% Clam Gulch Park Subdivision, plat #75-69 45U T 2N - R 12W 0.4600 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 8 & 9, Block 4, Vernon & Mary Osborn 12.5% Clam Gulch Park Subdivision, plat #75-69 45V T2N-R12W 0.2300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 10, Block 4, Robert W. & Casina G. Wilkins 12.5% ~ Clam Gulch Park Subdivision, plat #75-69 45W T 2N - R 12W 0.5650 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lots 11 & 12, Theodore Paullas 12.5% Block 4, Clam Gulch Park Subdivision, plat #75-69 Page 8 of 21 2/4/2003 EXHIBIT nAn NINILCHIK UNIT UNLEASED ACREAGE T2N-R12W 0.4925 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Mineral interest in Donald F. & Verona G. Smith 12.5% dedicated roads and easements in Clam Gulch Park Subdivision, plat #75-69 (est. 3 acres) 45Y T 2N - R 12W 6.0175 Theodore L. & Ann C. Morris 50% Uncommitted Section 29: Minerals underlying the Sterling Highway right-ot-way as it passes through Clam Gulch -~' Park Subdivision, plat #75-69 45Z T 2N - R 12W 0.1763 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 1, Block 3, Clam Gulch Park Subdivision, plat #75-69 45AA T2N-R12W 0.2550 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 2, Block 3, Scott Rumtield 12.5% Clam Gulch Park Subdivision, plat #75-69 45AB T2N-R12W 0.4700 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 3 & 4, Block 3, Sally A. Lawrence 12.5% Clam Gulch Park Subdivision, plat #75-69 45AC T 2N - R 12W 0.2550 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 19, Block 5, Debbie A. Hall 12.5% Clam Gulch Park Subdivision, plat #75-69 45AD T 2N - R 12W 0.2300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 18, Block 5, Donald R. & Debra A. Norvell 12.5% ..~ Clam Gulch Park Subdivision, plat #75-69 45AE T2N-R12W 0.3300 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 16 & 17, Block 5, Clam Gulch Park Subdivision, plat #75-69 45AF T2N-R12W 0.4400 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 14 & 15, Block Sheila A. Graham 12.5% 5, Clam Gulch Park Subdivision, plat #75-69 Page 9 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 2N - R 12W 0.4400 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 12 & 13, Block Patricia A. Lillian & Claralene Williams 5, Clam Gulch Park 12.5% Subdivision. plat #75-69 45AH T 2N - R 12W 0.1950 Theodore L. & Ann C. Morris 37.5% Uncommitted Section 29: Lot 11, Block 5, June A. Scheele, Mary L. Stoltman & Clam Gulch Park Subdivision, Nola E. Stoltman 12.5% plat #75-69 47 T 1 N - R 12W 20.5000 Helen L. Magionos 50% Uncommitted Section 5: Lot 4 Section 6: All of Lot 1 lying to the south and east of the -' Sterlinq Hiqhwav 67 T1N-R12W Section 4.0300 Theresa A. Wilson 50% Uncommitted 7: Lots 7 and 10 of Falls James L. Wilson 50% Creek Ridge 1978 Subdivision (Plat #H78-23 replatted #H78- 71), a part of government Lot 2 73 T 1 N - R 13W 10.3100 Wayne J. Woodhead and Ella Uncommitted Section 23: A part of Woodhead (H&W) 100% (Note - Government Lot 4 described possibly also Ella Woodhead, trustee of as Tracts A and E of the The Ella Woodhead Family Trust) Woodhead Subdivision platted in Plat #H-83-11 0 74 T 1 N - R 13W 7.9400 Robert N. Woodhead 100% Uncommitted Section 23: A part of Government Lot 4 described as Tract B of the Woodhead Subdivision platted in Plat #H- 83-110 - 75 T 1 N - R 13W 8.6100 Terry Lee Woodhead 100% Uncommitted Section 23: A part of Government Lot 4 described as Tract C of the Woodhead Subdivision platted in Plat #H- 83-110 Page 10 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 1 N - R 13W 7.7300 Dale Wayne Woodhead 100% Uncommitted Section 23: A part of Government Lot 4 described as Tract D of the Woodhead Subdivision platted in Plat #H- 83-110 77 T 1 N - R 13W 1 .0000 Elbert E. Hamilton and Gloria M. Uncommitted Section 27: That part of Lot 6 Hamilton (H&W, TBE) 100% Iyinq within the N/2NE/4NE/4 86 T 1 N - R 13W 1 .4300 William P. Cardwell 1 00% Uncommitted Section 27: A part of the S/2SE/4 lying north and west ~-- of the Sterling Highway described as Lot 9 of the Corea Bend Subdivision (platted as Plat #H85-15) 88 T1N-R13W 1 .0300 James Sheridan Crain Uncommitted Section 27: A part of the S/2SE/4 lying north and west of the Sterling Highway described as Lot 11 of the Corea Bend Subdivision (platted as Plat #H85-15) 89 T 1 N - R 13W 2.5700 Francis A. Ferguson 100% Uncommitted Section 27: A part of the S/2SE/4 lying north and west of the Sterling Highway described as Lots 12 and 13 of the Corea Bend Subdivision (platted as Plat #H85-15) --- 91 T 1 N - R 13W 1.2500 William C. Milhoan 100% Uncommitted Section 27: A part of the S/2SE/4 lying north and west of the Sterling Highway described as Lot15 of the Corea Bend Subdivision (platted as Plat #H85-15) Page 11 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 1 N - R 13W 1.3600 Wayne Bumpus and Paula Bumpus Uncommitted Section 27: A part of the (H&W) 100% S/2SE/4 lying north and west of the Sterling Highway described as Lot16 of the Corea Bend Subdivision (Dlatted as Plat #H85-15) 99 T1N-R13W 1.6352 Gaylord O. Smith & Luella Smith (H&W) Uncommitted Section 33: That part of 1% Government Lots 3 and 4 and Basil S. Bolstridge & Elizabeth W. the SE/4SE/4 lying east of Bolstridge (H&W) 1 % Sterlinq Hiqhwav --- 100 T1N-R13W 1.0816 David James Tyner 50% Gaylord Uncommitted Section 33: A part of O. Smith & Luella Smith (H&W) 1 % Government Lots 3 and 4 and Basil S. Bolstridge & Elizabeth W. SE/4SE/4 lying west of the Bolstridge (H&W) 1 % Sterling Highway more particularly described as Lots 1 and 2 of Seaside Terrace, platted in Plat #H82-1 01, replatted as Lot 1 A in Plat #H89-5 101 T 1 N - R 13W 4.8516 Gold Admiral, Ltd. 50% Gaylord O. Uncommitted Section 33: A part of Smith & Luella Smith (H&W) 1 % Government Lots 3 and 4 and Basil S. Bolstridge & Elizabeth W. SE/4SE/4 lying west of the Bolstridge (H&W) 1 % Sterling Highway more particularly described as Lots 3,4 and 5 of Seaside Terrace, platted in Plat #H82-1 01 ,-/ 102 T 1 N - R 13W 1.5288 Sherri L. Rock, Daniel A. Rock, Sandra Uncommitted Section 33: A part of J. Rock and Timothy D. Rock each Government Lots 3 and 4 and 25%x 50% SE/4SE/4 lying west of the Gaylord O. Smith & Luella Smith (H&W) Sterling Highway more 1% particularly described as Lot 6 Basil S. Bolstridge & Elizabeth W. of Seaside Terrace, platted in Bolstridge (H&W) 1 % Plat #H8?-1 01 Page 12 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE 103 T 1 N - R 13W 0.9984 John S. Davis & Marsha D. Davis Uncommitted Section 33: A part of (H&W) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 7 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-1 01 104 T 1 N - R 13W 2.4284 Norman E. Seitz & Linda L. Seitz Uncommitted Section 33: A part of (H&W) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) SE/4SE/4 lying west of the 1% ~ Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 8 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-1 01 105 T 1 N - R 13W 2.7456 Raymond C. Walker 50% Uncommitted Section 33: A part of Gaylord O. Smith & Luella Smith (H&W) Government Lots 3 and 4 and 1% SE/4SE/4 lying west of the Basil S. Bolstridge & Elizabeth W. Sterling Highway more Bolstridge (H&W) 1 % particularly described as Lot 9 of Seaside Terrace, platted in Plat #H8?-101 106 T 1 N - R 13W 1.3364 Kenneth W. Battley 2/3 x 50% (note- Uncommitted Section 33: A part of Jeffrey G. Pasco may claim some of Government Lots 3 and 4 and Battley's interest under Seaside Court) SE/4SE/4 lying west of the Patrick M. Davis 1/3 x 50% Sterling Highway more Gaylord O. Smith & Luella Smith (H&W) 1% particularly described as Lot 10 Basil S. Bolstridge & Elizabeth W. .~ of Seaside Terrace, platted in Bolstridge (H&W) 1% Plat #H82-1 01 and the minerals underlying Seaside 107 T 1 N - R 13W 1.3208 James E. Troutman & Susan E. Uncommitted Section 33: A part of Troutman (H&W) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 11 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-1 01 Page 13 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE ~. - - 108 T 1 N - R 13W 0.0502 Gaylord O. Smith & Luella Smith (H&W) Uncommitted Section 33: A part of 1% Government Lots 3 and 4 and Basil S. Bolstridge & Elizabeth W. SE/4SE/4 lying west of the Bolstridge (H&W) 1 % Sterling Highway more particularly described as Lot 12 of Seaside Terrace, platted in Plat #H8?-101 109 T 1 N - R 13W 1 .1076 Donald L. Caulkins & Denise D. Uncommitted Section 33: A part of Caulkins (H&W) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) ~ SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 13 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-1 01 110 T 1 N - R 13W 0.9724 Donald L. Caulkins & Michelle L. Uncommitted Section 33: A part of Caulkins (H&W) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 14 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-1 01 111 T 1 N - R 13W 0.1060 Gaylord O. Smith & Luella Smith (H&W) Uncommitted Section 33: A part of 1% Government Lots 3 and 4 and Basil S. Bolstridge & Elizabeth W. SE/4SE/4 lying west of the Bolstridge (H&W) 1 % Sterling Highway more particularly described as Lots ~ 15 & 16 of Seaside Terrace, platted in Plat #H82-101 112 T 1 N - R 13W 4.8880 Carl E. Jenkins & Doris C. Jenkins Uncommitted Section 33: A part of (H&W, TBE) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lots Bolstridge (H&W) 1 % 17,18,19 of Seaside Terrace, platted in Plat #H82-1 01 Page 14 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T1N-R13W 1 .2896 C. Edward Jenkins 50% Uncommitted Section 33: A part of Gaylord O. Smith & Luella Smith (H&W) Government Lots 3 and 4 and 1% SE/4SE/4 lying west of the Basil S. Bolstridge & Elizabeth W. Sterling Highway more Bolstridge (H&W) 1 % particularly described as Lot 20 of Seaside Terrace, platted in Plat #H8?-1 01 114 T 1 N - R 13W 2.0072 Carl E. Jenkins & Doris C. Jenkins Uncommitted Section 33: A part of (H&W, TBE) 50% Government Lots 3 and 4 and Gaylord O. Smith & Luella Smith (H&W) -' SE/4SE/4 lying west of the 1% Sterling Highway more Basil S. Bolstridge & Elizabeth W. particularly described as Lot 21 Bolstridge (H&W) 1 % of Seaside Terrace, platted in Plat #H8?-101 115 T1N-R13W 6.0000 Marguerite Hawkins 5% Uncommitted Section 34: NE/4NW/4 James Hawkins 5% Ian Hawkins, deceased 5% 117 T 1 S - R 13W 0.6800 Susanne Faye Windeler 100% Uncommitted Section 5: That part of Government Lot 2 lying east of the Sterlinq Hiqhwav 119 T1S-R13W 1.5800 Robert D. Steinke & Linda L. Steinke Uncommitted Section 5: A part of (H&W) 100% Government Lot 2 more particularly described as Lot 2 of Sunset Bluffs Subdivision as platted in Plat #H-79-5 120 T 1 S - R 13W 1.9900 Karen D. Maze 100% Uncommitted '-" Section 5: A part of Government Lot 2 more particularly described as Lot 3 of Sunset Bluffs Subdivision as platted in Plat #H-79-5 122 T1S-R13W 2.3700 Kathleen Kennedy 100% Uncommitted Section 5: A part of Government Lot 2 more particularly described as Lot 5 of Sunset Bluffs Subdivision as platted in Plat #H-79-5 Page 15 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T 1 S - R 13W 1.1700 John Inman & Dee Ann Inman (H&W) Uncommitted Section 5: A part of 100% Government Lot 2 more particularly described as Lot 12 of Sunset Bluffs Subdivision as platted in Plat #H-79-5 131 T 1 S - R 13W Section 5: 4.1495 Martha Gage Windeler Uncommitted That part of Government Lot 2 lying (possibly Susanne Faye Windeler) under the roadbed of the Sterling Highway and under the Leon Winnelp.r Hiohwav ¡:¡nd Persons Drive 140 T1S-R13W 1.5000 Steven Vanek, Jr. & Monica J. Vanek Uncommitted ~ Section 5: A part of the (H&W) 100% SW/4NE/4 more particularly described as Lot 8 of Bud's Acres Subdivision as platted in Plat #H85-69 141 T 1 S - R 13W 4.0000 Evelyn Terry McLaughlin 50% Uncommitted Section 5: N/2NW/4SW/4SW/4 Patricia Terry Lodge 1/3 less the west 132' thereof Lila Terry Hanson 1/6 141A T1S-R13W 1.0000 James C. Sanders Uncommitted Section 5: The west 132' of the N/2NW/4SW/4SW/4 147 T 1 S - R 13W 16.0000 David Roy Reaves 1/5 Uncommitted Section 7: SE/4NE/4 Carl Wayne Kinkead 115 149 T1S-R13W 20.6200 Laura Lee Tieman Life Estate (W. Lee Uncommitted Section 7: That part of the McKinley, remainderman) 100% NE/4SW/4 more particularly described as Lot 2 of Tieman Subdivision as platted in Plat c~ #H-85-129 150 T 1 S - R 13W 10.5400 Boyd Daniel Leman 100% Uncommitted Section 7: That part of the NE/4SW/4 more particularly described as Lot 3 of Tieman Subdivision as platted in Plat #H-85-129 a/d/a E/2NE/4NE/4SW/4 and that part of the E/2SE/4NE/4SW/4 lying north of the northerly right of way of the Sterling Highway Page 16 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE 151 T1S-R13W 31 .71 00 Kenai Peninsula Borough 100% Uncommitted Section 7: That part of the NW 14SE/4 lying north of the Sterling Highway, less and except that part described as Lot 1 of Aurora Vista Subdivision platted in Plat #H- 96-13 152 T1S-R13W 1.2900 Aurora Communications International, Uncommitted Section 7: That part of the Inc. 100% NW 14SE/4 lying north of the --- Sterling Highway more particularly described as Lot 1 of Aurora Vista Subdivision nl~ttp(i in PI~t #H-QR-11 153 T1S-R13W 7.0000 Steve Bates and Rebecca Bates Uncommitted Section 7: That part of the (H&W, TBE) NW/4SE/4 lying south of the Sterlinq Hiqhwav 154 T 1 S - R 13W 13.0000 Weathampstead Investments Limited Uncommitted Section 7: That part of the 100% NE/4SE/4 lying north of the Sterlinq Hiqhwav 155 T 1 S - R 13W 27.0000 Shirley J. Provence 100% Uncommitted Section 7: That part of the NE/4SE/4 lying south of the Sterlinq Hiqhwav 156 T1S-R13W 80.0000 Laura Lee Tieman Life Estate (W. Lee Uncommitted Section 7: That part of the McKinley, remainderman) 100% E/2SW/4 lying south of the '~ Sterling Highway and all of the SW 14SE/4 158 T1S-R13W 7.1540 David Roy Reaves 1/5 Uncommitted Section 8: That part of the Carl Wayne Kinkead 1/5 SW/4NW/4 lying west of the Sterling Highway aldla Lots 5 & 6 of the E. Mounts Subdivision as platted in plat 161 T 1 S - R 13W 40.0000 Laura Lee Tieman Life Estate (W. Lee Uncommitted Section 18: NE/4NW/4 McKinley, remainderman) 100% 162 T 18 - R 14W 35.9800 The Estate of Joseph Neustadter, Uncommitted Section 12: Lot 2 deceased 100% Page 17 of 21 2f4f2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE 163 T1S-R14W Section 33.2100 The Estate of Joseph Neustadter, Uncommitted 13: Lot1 deceased 100% 164 T1S-R14W Section 80.0000 Darwin E. & Kaye S. Waldsmith 75% Uncommitted 13: S/2SW/4 Gloria Millet 8.33333% George Maki 8.33333% Edward Lee Maki 8.33333% 166 T1S-R14W Section 3.3150 Deidre E. & John D. McCombs 75% Uncommitted 13: Tracts 1 &2 of Catledge- Wilson Subdivision, Tract A, Plat #78-32 170 T1S-R14W Section 0.7950 Bobby J. & Selena G. Gordon 75% Uncommitted ~ 13: Tract 9 of Catledge-Wilson Subdivision, Tract A, Plat #78- 32 172 T1S-R14W Section 2.0850 Gary & Mama Andes 37.5% Uncommitted 13: Tract 12 of Catledge- Gale R. Graham 37.5% Wilson Subdivision, Tract A, Plat #78-32 173 T 1 S - R 14W Section 2.3963 Walter L. Wilson 75% Uncommitted 13: Minerals underlying streets and roads in Catledge-Wilson Subdivision, Tract A, Plat #78- 3? 174 T1S-R14W Section 35.5118 Darwin Waldsmith 75% Uncommitted 13: Tracts B&C of Catledge Subdivision, plat #74-2075 176 T1S-R14W Section 14.6450 Gregory A. & Darlene M. Rozak 25% Uncommitted 13: That part of GLO Lot 2, John Gregory & Judith Ballentine 25% SE/4NW4 described as the Unsubdivided remainder of '-' Red Bluff Terrace 178 T1S-R14W Section 0.7500 Judith A. Ballentine 75% Uncommitted 13: Lot 3, Block 1, Red Bluff Terrace Subdivision Addition No.1, Plat #86-58 179 T1S-R14W Section 0.7500 David R. & Kodysz & Jean R. Uncommitted 13: Lot 2, Block 1, Red Bluff Gregorich 75% Terrace Subdivision Addition No.1, Plat #86-58 Page 18 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE T1S-R14W Section 0.9750 Michael S. & Cheryl B. Sutton 75% Uncommitted 13: Lot 3, Block 3, Red Bluff Terrace Subdivision, Plat #86- 57 182 T 1S - R 14W Section 4.6250 Gregory A. & Darlene M. Rozak 25% Uncommitted 13: Lots 1.4,5,7 & 8, Block 3, Judith A. Ballentine 25% Red Bluff Terrace Subdivision Addition No.1, Plat #86-57 & Lot 4, Block 2 & Lot 1, Block 3, Red Bluff Terrace Subdivision Plat #86-57 T1S-R14W Section 0.9150 William Kenneth DeFrang & Irene -- 183 Uncommitted 13: A tract in NE/4SW/4 lying Marie DeFrang (H&W, TBE) 100% east of Sterling Highway, beginning at a point on the centerline of the Sterling Highway bearing north 51 deg. 54 min. 32 sec. East a distance of 2273.5' from SW/c of 13-1S- 14W; TH. North 24 deg. 49 min. 45 sec. east along said centerline 109.6'; TH. south 89 deg. 20 min. 15 sec. east 376.4'; TH. south 0 deg. 39 min. 45 sec. west 100'; TH. north 89 deg. 20 min. 15 sec. west 421.3' to POB. 184 T1S-R14W Section 7.9970 John Pherson and Ethel Pherson Uncommitted 13: That part of the SE/4NW/4 (H&W) 100% ."-'" & NE/4SW/4 lying east of the Sterling Highway, less and except that Tract shown as Tract #183 of this exhibit (being the 0.915 acre DeFrang tract) and less and except Tract "A" of Pherson Acres Subdivision, plat H-2001-19 184A T1S-R14W Section 5.5530 Tim Moerlein Uncommitted ~ Tract "A" of Pherson Acres Subdivision, plat #H-200 1-19 Page 19 of 21 2/4/2003 EXHIBIT "A" NINILCHIK UNIT UNLEASED ACREAGE 186 T 1S - R 14W Section 12.2420 13: State of Alaska Highway Project Number F-021-1(3), Parcel Number 0118, as more particularly described by metes and bounds in a warranty deed dated 6/26/64 from Leonard Lee Catledge et ux to the State of Alaska, recorded in book 33, page 226 of the Homer Recording District T 1S - R 14W Section 0.5030 13: A 0.503 acre tract of land being State of Alaska Highway Project Number F-021-1(3), Parcel Number 0118-A, as more particularly described by metes and bounds in a warranty deed dated 7/28/64 from Calvin C. Hartman et ux to the State of Alaska, recorded in book 34, page 121 of the Homer Recording TOTAL: 704.2678 Page 20 of 21 2/4/2003 State of Alaska, Department of Transportation and Public Facilities Uncommitted --/' State of Alaska, Department of Transportation and Public Facilities Uncommitted ..-- ") ) ~ ... M MARATHON ~ Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 April 22, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached in triplicate is the Well Completion LOQ for Well Number Falls Creek #1 RD. Also attached for your records is the final well schematic and flow test report. Marathon requests that this information remain confident at this time. If you would like any other information, please contact me at 564-6305 or kdwalsh@marathonoil.com. This letter also serves as a formal written request to cease completion activities at this well. You granted approval to Marathon by email on 04/19/02 to cease the flow test and abandon attempts to obtain a four-point test on the single perforated interval in this well. The primary purpose to cease operations was complaints by a local resident(s) concerning the noise associated with the hydrocarbon gas venting from the test stack during flow test activities. It was agreed that Marathon would conduct the four-point test into the pipeline rather than the test stack following installation of the pipeline and startup of production. It was also agreed that Marathon would secure the well while awaiting construction of the pipeline' by installing a backpressure valve in the tubing head and chaining the master valves closed with a padlock. Sincerely, I~t.w~ Ken D. Walsh Advanced Production Engineer Enclosures RECEI\lED (' , : . i App ? "7 ?OQ:? ." ~_',J '- (.., Alaska Oil & GâS Cons. COIT¡m¡SBiOl' Anchorage Jun-20-02 08:46am F rcm-MARATHO~" ') +9155646489 ! T-S45 P.09/09 F-S84 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. ... 1. Status of W~II OILD . GASm 2. Namë of Operator MARATHON 011... COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 ¡~ Locatlön of Well afSurfaœ '1fiJ-';, __-..., 'VfI,·...I:I- 1898' FSL Be 2885' FEL, sec. 6, T1N, R12W, SM ~'l()CA':NC!¥q~ At top of Producing Int.elVal i Yefe " 1821' FSL& 5013' FEI-, sec. 6, T1N, R12W, SM ~ ~~_j At Total Depth ¡':1.,ff~.~~ 1830', FSL, & 5025' FEL., sec. 6, T 1N, R12W, SM ",:i",.~~~~::r;,,~\ -5, Elevation in feet(lndioate KB, DF, etc.) " " 6. L.eašë' Designation and Serià¡' No. 21.5' DF~GL. ADL-00590 12, Oate Spudded 13. Date T.D. Reacned 14. Datê'Comp:, Susp. or Aband:'"'''' ('5, WSilter Depth. it õffshot'e 16. No. Ö' Completions 7/31/2001 1:1/1512001 4/9/2002 N/A feet MSL. one 17, iotäi'D~pth (MD+TVD) 1a. Pll,Jg Back Depth (MÖ:"tvO) -19. Direc.tlonãi"sut'Vey'" 20. Depth wheré'SSSv ~I 21. rhickneea ~f Permafrost a900~~D/8322'lVO 'n" 8851'MO/S27S'TVD ._ ,,_Ye~ElN~p NJA feet MC N/A 22. Type electric or Other Logs Run Classification of ServiCE! Well SU$P~NDEDC ABANDO~F.oD SERVICEP !'.¡;'" . , ",!:i.=...q..~º.~ :¡'~L,:..·/; " ,", '...~, ..... ,. -. . ,,' " , ' ~.-.. ..-" ""., '." '.', ,.j i." Parmit Number 201-155. 8. ÄPI Number 133-10005-01 9. Unit or Leaseï\Jame Fans Creek Unit 10. well"'Number Fç¡lIs Creek #1 rd 11. Field and Poö¡ Falls CreekfTyonek 23 Platform Express (Array Induction, Density, Neutron, GR, Cal), Oipole Sonic, RFT .. ..". ¢ASING," LINER AÑtfCEM~NTiNG RECORP" "SETTING DEPTH MO TOP BOTTOM o 248' o 2468' o ~150' o 8900' 7¡;uJ~'~ :J'~0.3 ',"'b ?a c¡.y n-;, CASING SIZ6 WT. F'ER FT. 20" 97 13-3/8" 54.5 9-5/8" 40 4-1/2" t2,a GRADE HOLE SIZE ? 26" CEMENïlNG RECORD in place, 480sx. in place, 1660~.Ä i~,plaœ.. 1884sx in ølace, 1052 sx AMOUNT PULLED N/A N/A N/A N/A J-55 N-80 L.-80 18·5/8" 12~1/~~' 6-314" 24. perlOratlons open to Production (MD+TVO of Top and Bot'töm and"" interval, size and number) 25. ~IZE N/A TUBING ReCO~D CE~TH SET (MD) PA~KeR S.ET (MD) 8714' - 8750' MP (8'36' - 8172' TVO) '1'yonel<. T-3: 2-7/8" 2906 PJ 6 SPF 60 deg pna$ed 26..._ AëID. FRAë¡URE.-CEMENT SQUf:EZE. ETC. DEPTH INTE~VAL (MD) AMPUNõir'& KIND O~_MATEF<IAL usee N/A' "".. 27" PRODUCTIÓÑ'TEST Date First Production' -".. I Method of Operation (Flowing, gäs 11ft, etc.) N/A N/A .. " 'Date of Test .. Hours Tested 'PRODUcffoN FOR OIL-BBI- GAS~MCF WÃïER-BBL CHÖKE SIZE GAS-OIL RATIO 4/10/2002 1 TESi PERIOD -+ 0 276 0" 22/64 . N/A Flow1ublng Pres. Casing Pressure èALCULATED OIL-BBL GAS-MCF WATER-S'BL OIL GRAVITY-API (corr) . N/A 2300 24-HOUR RATE----. 9 .,. 6687 0 ... N/A ... 28. " . . - ~. . . . . Brief <\eSCriptioo of iitl'\Ol,;gy, porosity, fráctÌ1res, appa",ot"dlps and p"",.o"" of oil, gas or ......;. Submit ÇQ~CE IVED Interbedded sandstone, shale and coal. Sandstone contains methane with porosity ranges from 5--16%. RECEIVED JUN :,i, l l A'ækaOiI & Gas Cons. Commission G F ¡"d1ol~t Submit In Trfplicate i=orm ,O-4(}7 Rev. 7-1~aO JUN 2 0 2002 .. " CONTINUED ON REVERSE SIDE ~OiI'GalCons.~.'lIV A1~ qRDMS BFL ORiGiNAL JUN272D02 ~~-~+ cn--rl c;,J~e.~-h~ .~Pì'¡- ffi,lUIÆ.J ~~ z~ ZD:~'Z..-' ~ .,~b g·'D·O'::.. N ~\(rl~\kgf\well$\KaU33-6\AOGCOMPL '_dlb.xl:s ) ') 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Beluga 2077 2057 Tyonek 5513 4967 Tyonek T3 7597 7013 Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Tested 8714-8750' MD (8136-8172' TVD; Tyonek T3) Flowed 6.79 MMCFPD @ 2300# FTP R ['" (, ,'. ~,".. 8' \ , N- ~'''') i ~ ~"u'n '¡~ r ,\, .. ".: ~'''" ~ ''l;í Ii,." ... , ry) () f')OQf) f!l, !.. I·· , -:;, t.. I " I... ,"11 I \ ..-.. <..,.1 Alasl<a Oil &. Gas Cons, ComrnîSSith .Anchoraae 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed I~ lAJ~ Ken Walsh Title Advanced Production Eng. Date 4/22/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc,) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 :\ N:\drlg\sterling\su32-9\AOGCOMPL 1_dlb.xls ) Falls Creek #1 RD Sidetrack Whipstock @ 3133' CIBP @ +/- 3151' (WLM) Cement Retainer @ 3850' Cement Plug: 3850'-4011 ' Cement Retainer @ 4855' Cement Plug: 5200'-5991 ' Casing Damage @ 5315' Baker Model D @ 7545' Cement Plug: 7562'-7641' 27/8", 6.5ppf, N-80 8rd @ 7641' Original Perfs: 3900'-3911 ' 5290'-5315' 5442'-5470' 7562'-7600' Sqz Holes: 3884'-3886' 5275', 5326', 5419', 5490' 7550', 7615' ) . , M MAlABO. j TOC 2650' 4 1/2" X Nipple (3.813" 10) @ 5387' MD ~, ~~ )~I . g ~ ~ ~ I ~ ¡~ ~ ~ ~ ~ ~ t ~ í ~ ~ .~~ ~ Ii i ~ ., ~ ~ ~ ~ ~ ...J¡ L ::I z:: Tyonek T -3 Perforations: ::&: 1:: 8714' - 8750' MD 2-7/8" PJ 2906 6 spf l! r fI ~ i"\.:~'Ir~ 8809' MD PSTD __ TD: 8900'MD/8327'TVD , " ) ') Well Operations Summary Well: FALLS CREEK #1 RD Date DFS Ftg MD TVD Operations Summary MW 06/22/01 BEGIN TO RID RIG AND PREPARE TÔ MOVE. 06/23/01 0 0 8,395 0 RID RIG ON KBU 23X-6 LOCATION AND MOVE TO FALLS CREEK#1 LOCATION AND BEGIN R/U. 06/24/01 0 0 8,395 0 CONT. RlU GLACIER#1 RIG. 06/25/01 0 8,395 0 COMPLETE RIGGING UP RIG. R/U AND TEST CHOKE LINE AND CHOKE MANIFOLD. BLEED DOWN CSG PRESSURE WITH NO CHANGE IN TUBING PRESSURE. R/U SLICK LINE AND TEST LUBRICATOR. RIH WISLlCKLINE TOOLS AND AITEMPT TO PULL 27/8" OTIS "D" PLUG. COULD NOT LATCH PLUG. AITEMPTTO RUN 21/4" BAILER. COULD NOT PASS 36'. POOH AND FIND HYDRATE IN BAILER. 06/26/01 0 0 8,395 0 BREAK UP HYDRATE IN TUBING. RETRIEVE OTIS "D" PLUG @ 502' AND OTIS "D" PLUG @ 7441'. RUN 2.31" GAUGE TO BOITOM OF TUBING @ 7640'. AITEMPT TO PUNCH A HOLE IN 27/8" TUBING @ 7506'. RIH TO RETRIEVE COLLAR STOP. 06/27/01 0 8,395 0 RETRIEVE COLLAR STOP. RIU TO RUN APRS EL TUBING PUNCHER. EL BOP WOULD NOT TEST. RID APRS EQUIPMENT. MOBILIZE AND RIU SCHLUMBERGER TUBING PUNCHER EQUIPMENT. RIH AND PUNCH TUBING 7500' TO 7502'. NO CHANGE IN TBG OR CSG PRESSURE. AITEMPT TO CIRCULATE TUBING W/2980 PSI. 06/28/01 0 0 8,395 0 SHOOT TUBING PUNCHER GUNS: 7300' TO 7302' 8 HOLES. 7000' TO 7002' 8 HOLES. 6492'-6493.5' 7 HOLES. NO COMMUNICATION BETWEEN TBG AND CSG. 06/29/01 0 8,395 0 PUNCH TUBING 6006'-6008', 5494'-5496', 5006'-5008',4492'-4494', 3989'-3991 '(4SPF). NO INDICATION OF COMUNICATION BETWEEN TUBING AND CASING. BULLHEAD 65BBLS 6%KCL DOWN TUBING. BLEED OFF CASING PRESSURE THROUGH CHOKE. MONITOR TUBING AND CASING PRESSURE. 06/30/01 0 0 8,395 o MONITOR TUBING AND CASING. BLEED ANNULUS OFF AND FILL. MONITOR TUBING AND CASING. SET BPV. NID TREE. N/U BOP. 07/01/01 0 8,395 o TESTING BOPE. 07/02/01 0 0 8,395 o FINISH BOP TEST. PULL BPV. WORK STUCK TUBING AND AITEMPT TO CIRC. MONITOR WELL AND MOBILIZE SCHLUMBERGER. RlU SCHLUMBERGER EL. 07/03/01 0 8,395 0 PUNCH TUBING AND CIRCULATE. RIH AND CUT TUBING @ 8.67 7538' AND 3500'. POOH W/3500' OF 2 7/8" TUBING AND UD. CHANGE UPPER PIPE RAMS TO 4" . TEST PIPE RAMS. 07/04/01 0 0 8,395 0 COMPLETE BOP TEST. PIU DP. RIH WIINFLATABLE PACKER 8.7 AND SET @ 2952'. DUMP 8' SAND ON TOP AND PLACE A 100' CEMENT PLUG ON TOP OF SAND. POOH WI SEITING TOOL. PIU AND RACK BACK COLLARS AND HWDP WHILE WOC. 07/05/01 0 8,395 0 TEST CSG. NID BOP. NID WELLHEAD. FABRICATE 8.67 EXTENSION TO 95/8" STUB AND WELD ON. N/U WELLHEAD AND TEST. N/U BOP. 07/06/01 0 0 8,395 0 NIU BOP AND TEST. TEST 9 5/8" CSG. RIH W/8.5" BIT AND 8.7 BHA AND DRILL CEMENT. POOH. RIH AND RETRIEVE TAM INFLATABLE PACKER. 07/07/01 0 8,395 0 RIH W/8118" WASH SHOE AND 7 5/8" WASHPIPE. WASH OVER 8.7 2 7/8" TUBING F/3500' TO 3910. TORQUE INCREASED AND COULD NOT WASH PAST 3910'. POOH. UD DRAG TYPE SHOE AND PIU WAVE TYPE SHOE. 07/08/01 0 0 8,395 0 RIH W/7 5/8" WASHPIPE W/81/8" WAVE TYPE SHOE. MILL 6". 8.72 APPEARS TO BE MILLING METAL. POOH. RIH WIOVERSHOT BHA AND LATCH FISH. POOH. 07/09/01 0 8,395 0 POOH W/2 7/8" TBG FISH. UD 12 JOINTS, 406' OF 2 7/8" TBG. 8.7 TEST BOPE. RIH W/5 3/4" OVERSHOT BHA. LATCH FISH AND CIRCULATE. MAKE 2 1/8" GAUGE RUN TO 4139'. 07/10/01 0 0 8,395 0 MAKE GAUGE RUNS WIWIRELlNE. RELEASE FROM FISH AND 8.8 POOH W/OVERSHOT. RIH WIWASHOVER ASSY. CAN NOT PASS 3910'. POOH. RIH WI OVERSHOT ASSY AND LATCH FISH. RlU SCHLUMBERGER AND RIH AND FIRE JET CUrrER @ 3988'. POOH AND RID SCHLUMBERGER. · . , .~ Well: FALLS CREEK #1 RD Date 07/11/01 07/12/01 07/13/01 07/14/01 07/15/01 07/16/01 07/17/01 07/18/01 07/19/01 07/20/01 07/21/01 07/22/01 07/23/01 07/24/01 07/25/01 07/26/01 DFS 1 2 Ftg MD 8,395 8,395 8,395 8,395 8,395 8,395 8,395 8,395 8,395 8,395 8,395 8,395 5,458 5,488 5,496 5,496 ') Well Operations Summary TVD Operations Summary o P.O.H.I LAY DOWN 82' FISH / RUN 81/2" TAPERED Mill THRU PERFS @ 3910' -3914' / WASHING OVER FISH @ 4000' @ 200-300' PER HR./ MODERATE AMOUNTS OF GAS PRESENT o WASH-OVER TUBING TO 4600'/ LAY DOWN WASH PIPE AND RUN IN WITH OVERSHOT /WORK OVER TOP OF FISH - PUll 50000 OVER STRING WT.I lOST FISH I COULD NOT RE- ENGAGE I POH /PICK UP NEW EXT. AND. GRAPPLE IR.I.H. o lATCH FISH, PUll AND JAR WITH 120,000# OVERPUll I RUN JET CUTTER TO TOP OF FISH / SAT DOWN SOLID / ATTEMPT TO RELEASE OVERSHOT (TIGHT) I P.O.H. - HAD TWISTED 2 7/8" OFF @ 4519' LAVED DOWN 531.59' 27/8" TBG. (SPLIT COllAR ON lAST JT. lEAVING 27/8" THREAD lOOKING UP) PICK UP WASHPIPE I WASHING FROM 4600' o WASH TO 5129' I P.O.H. AND P/U 27/8" OUTSIDE CUTTER -R.I.H.I CUT @4557' AND lA V DOWN 32.30 2 7/8" I GOOD CUT I RUNNING IN WI OVERSHOT TO NEW TOP OF FISH @4557' I Will FOllOW WITH JET CUT @ 5129' o R.I.H. WI OVERSHOT AND ENGAGE FISH / RUN GUAGE RING TO BTM.; RUN JET CUTTER AND CUT @5126' (3' ABOVE Fill) LA V DOWN 571' 27/8" TBG. RUNNING IN WI WASHPIPE RIGGED WI PilOT Mill IN DRIVE BUSHING TO DRESS OFF T.O.F. @ END OF EA. W.P. RUN o WASH OVER 27/8'" TBG. FROM 5129' TO 5308' I P.O.H. TO INSPECT SHOE (INSIDE -BOTTOM OF SHOE CUT SMOOTH @45-60 DEGREES) TEST B.O.P.S I WAIT ON TOOLS FROM BAKER I o RUN IN W/6 1/2" X 4 7/8" SHOE ON 5 3/4" WASHPIPE I WORK OVER TOP OF FISH @5126' ; WASH DOWN TO 5308' WASH WITH SHOE 5308' TO 5311' / POH (SMALL CHUNK OF 9 5/8"COUPLlNG WEDGED IN SHOE) I RUN IN W/ OVERSHOT - CHASE FISH 5126' TO 5220' / POH WET OLAV DOWN 99.14' 27/8" TBG.I RUN IN W/5 3/4" SHOE, "T" DOG, AND 6 JTS. 5 3/4" WASHPIPE I RECOVER 74.75' 27/8" TBG. / RUN IN W/ TAPERED Mill AND STRING Mill o LA V DOWN TAPERED MilL AND STRING MILL / R.I.H. AND MilL W/5 3/4" SHOE (SHOE WAS COMPLETELY WORN OUT, JUNK BASKET FULL OF CASING PIECES AND CEMENT CHUNKS) IRUNNING IN WITH (SMALL) TAPERED MILL o MILL TO 5314' I LAY DOWN Mill AND PIU JET BASKET - JETI WASH 5267' TO 5315' / RECOVER FIST SIZE CHUNK OF CEMENT FROM BASKET (NO METAL) RUN IN WITH JUNK MilL AND (3) JUNK BASKETS I MILLED OR DRILLED 5312' TO 5323'1 TORQUEV I PUMP SWEEPIINO METAL CUTTINGS SEEN I P.O.H. o P.O.H.I CLEAN FUll JUNK BASKETS /MAKE UP BHA AND SET ON JUNK @28' (BELOW WEAR RING) ATTEMPT TO FISH - KNOCKED DOWNHOLE I R.I.H. WI SHOE AND SINGLE JT. WASHPIPE/WASH 5322' TO 5340 I 'P.O.H. OLAV DOWN WASHPIPE / PICK UP MILL AND MilLING WI lESS THAN 1000# TO ATTEMPT TO GET INTO CASING o MilLING TO 5363' I LAY DOWN MILLING ASS'Y. AND PICK UP SHOE AND W ASHPIPE / WASHING OVER TUBING @ 40' - 50' PER HR. TO PERFS @ 5442' / WASHING @ 2' TO 5' PER HR. THRU PERFS o WASH-OVER TUBING TO 5468' / POH I TEST BOP'S / RIH / WASHOVER T05488' o WASH OVER TBG. 5468' TO 5496' I RETRIEVE 95.77' BADLY SCARRED ,WRAPPED UP TBG.I R.I.H. WITH NEW SHOE / WASH OVER TBG. FROM 5496' TO 5911' (415') P.O.H. o RUN IN TO CUT TBG. WITH OUTSIDE CUTTER I CUT @ 5881' ( 30' UP FROM BTM. OF WASH) P.O.H. NO RECOVERY / REMOVED 18" X 2" FLAT CUT PIECE OF TBG. FROM CUTTER / R.I.H. WITH NEW CUTTER MW 8.8 8.8 8.8 8.7 8.7 8.7 8.8 8.8 8.8 8.8 8.8 8.8 8.75 8.7 8.7 8.7 '. ... Well: FALLS CREEK #1 RD Date 07/27/01 07/28/01 07/29/01 07/30/01 07/31/01 08/01/01 08/02/01 08/03/01 08/04/01 08/05/01 08/06/01 08/07/01 08/08/01 08/09/01 08/10/01 08111101 08/12/01 08/13/01 08/14/01 08/15/01 08/16/01 DFS Ftg 2 3 4 358 5 6 7 8 9 10 11 12 13 14 15 16 17 MD 5,881 5,881 3,151 3,109 20 3,130 4 3,134 173 3,307 3,665 631 4,296 579 4,875 365 5,240 435 5,675 6,029 6,650 6,905 7,430 ') ) Well Operations Summary TVD o Operations Summary CUT TBG. @ 5881' I P.O.H. I LAY DOWN 388.40' 27/8" TBG. I R.I.H. WI NEW SHOE I MILLNG OVER PIPE @ 5991 @ 0600 o WASH OVER FISH TO 5992' I P.O.H.I MILL WAS DESTROYED I - 8.7 IPREPARE TO PLUG BACKI RIH WI RETAINER TO 5225' I TEST LINES I ESTABLISH INJECTION RATES I MIX AND PUMP CMT. I SPOT 13 CU. FT. ON TOP REVERSING OUT @ 6AM o SET RETAINER @ 3850' / SQUEEZED CMT. UNDER AND SPOT 8.7 CMT. ON TOP OF RETAINER I R.I.H. WI CASING SCRAPER TO 3300' I RIG UP WIRELlNE AND SET BRIDGE PLUG @ 3151' I TEST CASING AND BRIDGE PLUG TO 2500 PSI FOR 30 MIN .--O.K. I START PICKING UP WHIPSTOCK, MILLS, AND BHA o RUN IN WITH WHIPSTOCK I SET ON BAKER BRIDGE PLUG I 8.7 PUSHED PLUG DOWNHOLE TO 3159' - (5) FT. BELOW 9 5/8" COUPLING I P.O.H AND PICK UP MILLING ASS'Y. I PUSH PLUG TO TOP OF CEMENT ON RETAINER @ 3815' I P.O.H.I RUN HOWCO E-Z DRILL I SET @31 09 ' I RUNNING IN TO SET 30000# ON E-Z DRILL @ 0600 3,074 SET 30000# DRILLSTRING ON E-Z DRILL I TEST CASING AND 8.8 E-Z DRILL TO 2500 PSI I P.O.H./ S.L.M. LAY DOWN BHA I TEST B.O.P.'S / PICK UP WHIPSTOCK I R.I.H. I ORIENTATE 20 DEGREES RIGHT OF HIGH SIDE I CUTTING WINDOW AND OPEN HOLE FROM 3103' 'TO 3130' 3,078 DRILL NEW HOLE F/3130' TO 3134'. PUMP SWEEP AND CIRC. 8.8 CLEAN. MIX NEW MUD. DISPLACE WELL TO NEW MUD. PERFORM LOT. POOH. 3,237 POOH W/MILL ASSY AND UD. P/U 6 3/4" BIT AND STEERABLE 8.9 ASSY AND RIH. DIR DRILL AND SURVEY F13134' TO 3307'. TROUBLE SHOOT MUD PUMP#2. 3,526 WORK ON MUD PUMP#2 AND RIU BJ UNIT. CHANGE LINERS 9.1 IN PUMP#1. RIH AND TEST BJ UNIT. ClR DRILL AND SURVEY F/3307' TO 3542'. CBUX2W/BJ UNIT. DIR DRILL AND SURVEY F/3542' TO 3665'. 3,985 DIR DRILL AND SURVEY F/3665' TO 3979'. CBUX2. POOH TO 9.3 3130'. CBU. SLUG PIPE AND POOH. C/O BIT. RIH DIR DRILL AND SURVEY F/3979' TO 4296. 4,428 CBUX3. DIR DRILL AND SURVEY F/4296' TO 4610'. CBUX3. 9.2 POOH TO 3110. CBU. SERVICE RIG. RIH. ClR DRILL AND SURVEY F/4610' TO 4875. 4,737 DRILL F/4875' TO 4923'. CBUX3. POOH. C/O BIT. RIH. DRILL 9.3 F/4923' TO 5240'. CBUX2. 5,131 CBU. DRILL F/5240' TO 5365'. CBUX3. DRILL F/5365' TO 5675'. 9.4 CBUX3. POOH. 5,480 tEST BOP"S I R.I.H. WI BIT #6 I SLIP AND CUT DRILL LINE I 9.4 RJ.H.I DRILLING-SLIDING 5675'- 6029' 6,078 DRILL I SLIDE TO DROP ANGLE I DRILL TO 6650' 9.3 6,335 DRILL TO 6698' I TRIP FOR BIT, BRAKE REPAIR, AND M.W.D. BATTERY I WORKING TO REPAIR GEAR END OF #2 PUMP AND DRILLING @6905' 6,955 DRILL I SLIDE I DRILL FROM 6905' TO 7430' 7,815. 7,242 DRILL ; SHORT TRIP TO 6550' ; DRILL AND SLIDE TO 7815 '1 CIRCULATING SAMPLES FOR LOGGERS; PREPARE TO P.O.H. 8,125 7,402 P.O.H. FROM 7815' I CHANGE OUT BIT AND REPLACE MOTOR I PICK UP (11) HEAVI - WATE R.I.H. AND DRILL 8,800 8,227 DRILLING FROM 8125' TO 8800' 8,900 8,900 8,323 DRILL TO 8900 (TD) I CBU AND SWEEP / SHORT TRIP TO WINDOW I CBU AND HIGH vise SWEEP I P.O.H. AND RIG UP FOR LOGS 8,323 LOG WELL I TEST BOP'S I R.I.H. FOR LAST CLEANOUT BEFORE CASING MW 8.7 9.4 9.3 9.3 9.3 9.2 9.2 9.3 , ~, ) ) Well Operations Summary Well: FALLS CREEK #1 RD Date DFS Ftg MD TVD Operations, Summary MW 08/17/01 18 8,900 8,323 + R.I.H. FOR CLEANOUT PROIR TO RUNNING CASING / C.B.U. 9.4 AND PUMP HIGH VISC. SWEEP / PUMP GYRO TO BOTTOM AND P.O.H. LAYING DOWN DRILLPIPE AND B.H.A./ SURVEYS WHILE P.O.H. RIG UP AND START RUNNING CASING 08/18/01 19 8,900 8,323 RUN 4 1/2" CSG. ; CIRC. 2 1/2 HOLE VOLUMES @ 3 TO 8 9.6 BBLS. PER MINUTE / MIX AND PUMP CEMENT PER PROGRAM / DISPLACE WITH KCL @6 B.P.M. ; SLOW TO 1.5 B.P.M. AND 3100 PSI TO BUMP PLUG C.I.P.@1220 HRS. / BLEED OFF - FLOATS HELD / W.O.C./ RIGGING DOWN 08/19/01 20 8,900 8,323 W.O.C. / START RIGGING DOWN FOR MOVE / TEST 41/2" CASING AND 9 5/8" X 4 1/2" ANNULUS / NIPPLE DOWN STACK AND NIPPLE UP AND TEST TREE / RELEASE RIG FROM FALLS CREEK #1 @ 0600 HRS. MARATHON OIL COMPANY ) 4/7/2002 DAILY VVELL OPERATIONS REPORT PAGE 1 OF 1 DATE: PBTD: WORK DONE: FILL DEPTH/DATE: OTHER: FIELD: 8790' MD LINER: Tagged PBTD at 8790' MD Initial Completion RU BJ Services Coil Tubing Unit. SUMMARY OF OPERATIONS Wildcat N/A CASING: TREE CONDITION: CREW: WELL #: Falls Creek #1 4-1/2",12.6 #,L-80 new New 4-1/16", 5K w/4" Bowen cap Pollard slickline/BJ coil tubing 5/ Hrs. 4-1/16", 5K Christmas tree has been installed and tested to 5,000 psi. Backpressure valve is removed. PTS ll'ell testers have rigged up. MOC bullet and open-top flat tanks have been delivered and set on bermed liner. Diesel fuel truck has been delivered and set on bermed liner. Two Veco light plants delivered to location. Larry Keen supervised PTS rig up. Weaver fork lift and MOC methanol house on location. 8:00 Pollard slickline on location. Hold PJSM to discuss hazards and operations. PTS v.ell testers making final tie-ins. RU Secorp H2S and LEL sensors. 8:30 MIRU Pollard slickline equipment. Made up Pollard lubricator, WL BOP, flow tee. Tied new rope socket and performed twist test on wire. Made up 1.5" tool string consisting of 2 knuckle jts., 2 roller stems, 1 regular stem, oil jars, spang jars, crossover, and 3.5" OD gauge ring. Set lubricator and BOP on top of swab valve with Veco crane and NU to 4" Bowen. RIH INith gauge 9:00 ring and tagged PBTD at 8790' MD. 9:30 POOH with tool string. Changed out to 3.80" OD gauge ring. 10:00 RIH with 3.8" gauge ring and tagged 4-1/2" "X" profile nipple at 5387' MD. 10:30 POOH with tool string. RD Pollard slickline. SWIFN. 12:00 Veco 40-ton crane operator and BJ coil personnel on location. Spotted coil tubing unit and rigged up. Pressure tested BJ pump lines and CT BOP to 4500 psi with 50:50 methanol water. Pressure tested PTS line from tree to manifold to 4500 psi with 18:00 methanol water. Pressure tested line from manifold to separator to 800 psi with methanol water. 19:00 SDFN Vendor Marathon Pollard Veco Alaska Oil Sales PTS Testers Various Larry Keen R&K Equipment Supervision Slickline Crane Diesel ( gals) Well test equipmenUcrew Lite plnts/tanks/LEUfuel/forklift Supervision Trucking Costs Forward...... DAILY COST: $27,610.00 CUM: $27,610.00 Daily Cost $600.00 $2,340.00 Cumulative Cost $600.00 $2,340.00 $0.00 $650.00 $19,500.00 $3,400.00 $1,120.00 $0.00 $0.00 $0.00 $650.00 $19.500.00 $3,400.00 $1,120.00 REPORTED BY: Ken Walsh MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: PBTD: WORK DONE: FILL DEPTH/DATE: OTHER: 4/8/2002 FIELD: 8806' MD LINER: Jet well dry to 8806' MD Initial Completion Trapped 1800 psi nitrogen pressure on well. Wildcat N/A CASING: TREE CONDITION: CREW: WELL #: Falls Creek #1 RD 4-1/2",12.6 #,L-80 new New 4-1/16", 5K w/4" Bowen cap BJ coil tubing 11 Hrs. SUMMARY OF OPERATIONS 7:00 BJ Services coil tubing and nitrogen, Veco crane, and PTS well test personnel on location. Reset coil tubing injector head on CT BOP. 8:00 Hold PJSM to discuss hazards and operations. Cool down pumps with nitrogen. 8:30 Pressure test CT BOP md connections to 3500 psi with methanol water. Displaced methanol water to tank with nitrogen. Opened well and RIH with 2" OD wash nozzle on 1-3/4" coil tubing. Began pumping 500 scfm N2 at 560' MD to unload KCL water from well bore 9:00 through PTS test equipment. Increased nitrogen rate to 750 scfm to maintain returns at 5980'. Continued RIH with CT pumping N2 at 750 scfm to 8790' MD and washed down to solid PBTD of 8806' MD. Increased N2 rate to 1000 scfm and 10:30 monitored fluid returns. Shut in flow back lines once full fluid recovery was achieved. POOH with coil tubing pumping nitrogen at 1000 scfm to pressure up the well bore to 1800 psi surface pressure. The trapped nitrogen pressure will be 0:30 used to minimize underbalance when perforating the dry wellbore tomorrow am. Ceased pumping nitrogen. SWIFN and began rigging down BJ Services coil tubing unit and nitrogen pumper. Will spot CT unit at back of Falls Creek Pad and send N2 pumper 14:00 to BJ yard. Skid-mounted fluid pumper will be staged at MGO pad. Note: Brian Havelock and geologist with DNR to witness flow test tomorrow. Vendor Marathon BJ Services Veco Equipment Supervision CT/Nitrogen Crane Daily Cost $600.00 $44,479.00 $1,950.00 PTS Testers Various Larry Keen R&K Well test equipmenUcrew Lite plnts/tanks/LELlfuellforklift Supervision Trucking $6,000.00 $1,700.00 Cumulative Cost $600.00 $44,479.00 $1,950.00 $0.00 $6,000.00 $1,700.00 $0.00 $5,500.00 $0.00 $0.00 $27,610.00 $5,500.00 Costs Forward... ... DAILY COST: $60,229.00 CUM: $87,839.00 REPORTED BY: Ken Walsh ) MARATHON OIL COMPANY CAlLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: PBTD: WORK DONE: FILL DEPTH/DATE: OTHER: 4/9/2002 FIELD: 8809' MD (WLM) LINER: Perforated 8714'-8750' MD Initial Completion Ran GRljCCL correlation strip from PBTD to 5350' MD. Wildcat N/A CASING: TREE CONDITION: CREW: WELL #: Falls Creek #1RD 4-1/2",12.6 #,L-80 new New 4-1/16", 5K w/4" Bowen cap Schlumberger wireline 12 Hrs. SUMMARY OF OPERATIONS 7:00 Schlumberger wireline, Veco crane, and PTS well test personnel on location. MIRU Schlumberger skid-mounted wireline unit. Hold PJSM to discuss hazards. Made up Schlumberger 5" lubricator. Strirg wireline through lubricator and install grease head. Retied rope socket 7:30 to control head for 0.23" wireline. Made up grease hoses to packoff. Made up GunGR (CCL and GR), SAFE iring head, and perforating guns to control head. PU and NU wireline lubricator to BOP. Set WL flow tee and 9:00 and BOP on top of swab valve with Veco crane and NU to 4" Bowen. 11 :30 Opened tree valves. SI \M-IP was 1750 psi. Pressure test lubricator to wellhead pressure with nitrogen in well bore. RIH with GunGR, SAFE firing head, and 2.875" HSD perforating guns loaded 6 SPF 60 degree phased with PJ 2906 HMX 19.5 gm. charges to perforate 8730'-8750' MD. Tagged PBTD at 8809' MD. Correlated depth with Platform Express openhole log run 08/15/2001. Ran a correlation strip of CCUGR from PBTD to 5350' MD. RIH and perforated the Tyonek T3 interval 8730'-8750' MD. After perforating, the wellhead pressure increased 12:00 from 1750 to 2250 in 5 minutes and to 2750 psi in 15 minutes. 13:30 POOH with perforating guns, firing head, and GunGR. All soots fired and round. PU and RIH with GunGR, SAFE firing head, and 2.875" HSD perforating guns loaded 6 SPF 60 degree phased with PJ 2906 HMX 19.5 gm. charges to perforate 8714'-8730' MD. Correlated depth with Platform Express openhole log run 08/15/2001. AttEmpted to draw the pressure down to 1750 psi but could only achieve 2450 psi at 3.2 MMscfcl rate (with Nitrogen in the wellborel). After perforating, the wellhead pressure increased to 2800 psi 15:30 in 15 minutes. 17:00 POOH with perforating guns, firing head, and GunGR. All soots fired and round. 17:30 RDMO Schlumberger wireline. 19:30 Put well to test with 2850 psi shutin WHP. Note: Brian Havelock and Luke Bogess with DNR on location to witness flow test today. Vendor Marathon Equipment Supervision Daily Cost $600.00 Cumulative Cost $600.00 $0.00 $2,200.00 $30,267.00 $6,500.00 $1,700.00 $0.00 $0.00 $0.00 $0.00 $87,839.00 Veco Schlumberger PTS Testers Various Larry Keen Crane Perforators Well test equipment/crew Lite plnts/tanks/LEUfuel/forklift Supervision $2,200.00 $30,267.00 $6,500.00 $1,700.00 Costs Forward...... DAILY COST: $41 ,267.00 CUM: $129.106.00 REPORTED BY: Ken Walsh - '. TO "'roduction Testing Services 04/09/02 Tubing Static Diff. Meter Gas Cum Fluid H20 Fluid Fluid Cum. Temp Pres. Pres Temp Orifice Rate Gas Meter MTR BSW Gain Rate Fluid of psi(g) in. of H20 F in. MMCFn; MMCF BBL BBL % BBL BBLID BBL _ FallsCreek#l.M...W: 04/04/02 Clock Cum Choke Tubing Date time Time Comments Size Pres. IIA O/A mm/ddlyy hh/mm hr. in. psi(g) 04/04/02 20:35:00 0 Arrive in kenai -Check in 04/05/02 6:00:00 9.417 On location - begin move/RU 04/06/02 7:30:00 34.92 Run all lines/pipe and safety system 04/07/02 7:30:00 58.92 Complete RU-Seacorp on location w/detection equi:>. 04/07/02 18:00:00 69.42 Press.Test all lines 800/4700# -Good!! 04/08/02 7:00:00 82.42 PTS/CTU on location I 04/08/02 8:40:00 84.08 Safety Meeting I 04/08/02 9:17:00 84.7 Open choke to FB tank(900psi TP) 04/08/02 10:00:00 85.42 Continue unloading well to FB tank 04/08/02 11 :00:00 86.42 Continue unloading well to FB tank 04/08/02 12:10:00 87.58 36 in. tank strap(approx.133 bbls recovered 04/08/02 12:11 :00 87.6 shut in @ manifold 04/08/02 14:40:00 90.08 Block in tree @ 1800 psi 04/08/02 14:40:00 90.08 Bleed down CTU I 04/09/02 7:00:00 106.4 Schlumberger on location RU 04/09/02 10:20:00 109.8 Dead weight tested hi-press Recorder 04/09/02 14:08:00 113.6 Perfs Shot 1775 04/09/02 14:13:00 113.6 2300 04/09/02 14:18:00 113.7 2500 04/09/02 14:20:00 113.8 2590 04/09/02 14:22:00 113.8 2610 04/09/02 14:24:00 113.8 2650 04/09/02 14:26:00 113.9 2660 04/09/02 14:28:00 113.9 2670 04/09/02 14:30:00 113.9 2680 04/09/02 14:32:00 114 2690 04/09/02 14:34:00 114 2690 04/09/02 14:36:00 114 2690 04/09/02 14:38:00 114.1 2690 04/09/02 14:40:00 114.1 2690 04/09/02 14:45:00 114.2 2690 04/09/02 14:50:00 114.3 2700 04/09/02 14:55:00 114.3 2700 04/09/02 15:00:00 114.4 2700 04/09/02 15:02:00 114.5 2700 04/09/02 16:05:00 115.5 Drawing down well 2700 04/09/02 16: 15:00 115.7 I 2450 04/09/02 16:45:00 116.2 2450 ) ) o o o o o o o 44 44 0.000 3.299 3.234 o o o o o o 0.000 0.023 0.091 o o o o o o o o o o 340 340 o 35 35 o 0.000 110 2.000 130 2.000 Prepared by pts 4/19/2002 Oil Oil Cum Gain Rate Oil BBL BBLID BBL o 0' o o o o o o o o o H20 , Gain BBL CUM H20 BBL H20 Rate GOR Solids BBLID MMCFIBBL % "---. ~- o o o o o o o o o o o o 0.0 0.0 0.0 Page 1 .,.J ~ J FallsCreek#1 -~-tl4 04/09/02 TO 04/10/02 Clock Cum Choke Tubing Tubing Static Diff. Meter Gas Cum Fluid H2O Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date time Time Comments Size Pres. IIA OIA Temp Pres. Pres Temp Orifice Rate Gas Meter MTR BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids mmldd/yy hhlmm hr. in. psi(g) of psi(g) in. of H2O F in. MMCF~ MMCF BBL BBL % BBL BBLID BBL BBL BBLID BBL BBL BBL BBLID MMCF/BBL 0/0 04/09/02 17:00:00 116.4 Shut in @ ck. 2780 0 0 46 0 0 100 2.000 0.000 0.091 0 0 0 0 0 0 0 0 Q 0 0 0 0.0 04/09/02 17:02:00 116.5 2810 0 0 46 0 0 90 2.000 0.000 0.091 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 17:04:00 116.5 2810 0 0 46 0 0 80 2.000 0.000 0.091 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 17:10:00 116.6 2820 0 0 46 0 0 70 2.000 0.000 0.091 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 17:15:00 116.7 2825 0 0 46 0 0 60 2.000 0.000 0.091 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 17:30:00 116.9 2810 0 0 46 0 0 50 2.000 0.000 0.091 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 19:30:00 118.9 2810# S.I.P. Open well thru.septerator to flare on 15/64 choke 04/09/02 20:00:00 119.4 15.000 2440 0 0 43 380 40 82 2.000 3.848 0.492 0 0 0 0 0 0 0 0 0' 0 0 0 0.0 04/09/02 20:30:00 119.9 15.000 2510 0 0 56 300 34 70 2.000 3.187 0.565 0 0 0 0 0 0 0 0 0, 0 0 0 0.0 04/09/02 21 :00:00 120.4 15.000 2640 0 0 52 300 27 76 2.000 2.821 0.628 0 0 0 0 0 0 0 0 0'1 0 0 0 0.0 04/09/02 21 :00:00 120.4 Change choke to 18/64 04/09/02 21 :30:00 120.9 118.0001 2575 0 0 51 300 28 78 2.000 2.867 0.687 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 22:00:00 121.4 18.000 2600 0 0 50 400 27 76 2.000 3.270 0.751 0 0 0 0 0 0 0 0 01 0 0 0 0.0 ) 04/09/02 22:00:00 121.4 Change choke to 20/64 04/09/02 22:30:00 121.9 20.000 2495 0 0 50 400 41 58 2.000 4.118 0.828 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 23:00:00 122.4 20.000 2500 0 0 51 400 38 58 2.000 3.965 0.912 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/09/02 23:30:00 122.9 20.000 2500 0 0 51 400 38 56 2.000 3.975 0.995 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 0:00:00 123.4 20.000 2500 0 0 51 400 41 53 2.000 4.144 1.079 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 0:30:00 123.9 20.000 2500 0 0 51 400 39 53 2.000 4.042 1.165 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 1 :00:00 124.4 20.000 2500 0 0 52 400 36 52 2.000 3.889 1.247 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 1:30:00 124.9 20.000 2500 0 0 52 400 35 52 2.000 3.834 1.328 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 2:00:00 125.4 20.000 2500 0 0 52 400 35 52 2.000 3.834 1.408 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 2:00:00 125.4 Change choke to 21/64 04/1 0/02 2:30:00 125.9 121.0001 2460 0 0 52 400 41 48 2.000 4.171 1.491 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/10/02 3:00:00 126.4 21.000 2600 0 0 50 400 20 62 2.000 2.863 1.564 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 3:00:00 126.4 Choke was iceing up , pumped methanol to thaw 04/1 0/02 3:30:00 126.9 21.000 2400 0 0 48 400 42 56 2.000 4.179 1.638 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 4:00:00 127.4 21.000 2460 0 0 48 400 46 54 2.000 4.384 1.727 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/10/02 4:30:00 127.9 21.000 2375 0 0 48 660 47 41 2.000 5.944 1.834 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/10/02 4:30:00 127.9 Change choke to 20/64, freezing up 04/1 0/02 5:00:00 128.4 20.000 2450 0 0 48 600 43 54 2.000 5.280 1.951 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 5:30:00 128.9 20.000 2400 0 0 49 600 45 47 2.000 5.458 2.063 0 0 0 0 0 0 0 0 0 0 0 0 0.0 04/1 0/02 6:00:00 129.4 20.000 2400 0 0 57 600 50 46 2.000 5.762 2.180 0 0 0 0 0 0 0 0 0 0 0 0 0.0 ) 04/1 0/02 7:00:00 130.4 20.000 2390 0 0 62 610 48 44 2.000 5.716 2.419 0 7.3 100 0 0 0 0 0 0 1.4 7.3 67.2 0.0 04/10/02 7:30:00 130.9 20.000 2390 0 0 62 610 48 44 2.000 5.716 2.538 0 7.3 100 0 0 0 0 0 0 0 7.3 0 0.0 04/10/02 8:00:00 131.4 20.000 2380 0 0 63 615 49 44 2.000 5.802 2.658 0 7.3 100 0 0 0 0 0 0 0 7.3 0 0.0 04/1 0/02 8:30:00 131.9 20.000 2375 0 0 63 615 49 44 2.000 5.802 2.779 0 7.3 100 0 0 0 0 0 0 0 7.3 0 0.0 04/10/02 9:00:00 132.4 20.000 2375 0 0 63 615 48 40 2.000 5.778 2.899 0 7.3 100 0 0 0 0 0 0 0 7.3 0 0.0 Prepared by pts 4/19/2002 Page 2 J1I FallsCreek#1 . ~_ 04/10/02 TO Clock Cum Choke Tubing Tubing Static Diff. Meter Gas Cum Fluid H2O Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date time Time Comments Size Pres. I/A O/A Temp Pres. Pres Temp Orifice Rate Gas Meter MTR BSW Gain Rate Fluid Gain Rate Oil . Gain H2O Rate GOR Solids mmldd/yy hh/mm hr. in. psi (g) of psi (g) in. of H2O F in. MMCFn; MMCF BBL BBL % BBL BBL/D BBL BBL BBL/D BBLI BBL BBL BBL/D MMCFIBBL % 04/1 0/02 9:30:00 132.9 20.000 2375 0 0 63 615 51 40 2.000 5.956 3.022 0 7.3 100 0 0 0 0 0 0 0 7.3 0 0.0 04/10/02 10:00:00 133.4 20.000 2375 0 0 63 615 51 40 2.000 5.956 3.146 0 10.8 100 0 0 0 0 0 0 3.5 10.8 168 0.0 04/10/02 10:20:00 133.8 Meth pump down 2400 0 0 65 620 21 42 2.000 3.828 3.214 0 11.7 100 0 0 0 0 0 0 0.9 11.7 64.8 0.0 04/10/02 10:25:00 133.8 Clearing pump 2560 0 0 65 620 22 44 2.000 3.906 3.227 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10/02 11 :00:00 134.4 Choke iced @ seat 2540 0 0 65 620 24 48 2.000 4.054 3.324 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10/02 11 :30:00 134.9 Pump On Line 2500 0 0 64 620 26 49 2.000 4.213 3.410 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10102 12:00:00 135.4 Choke seat clear 2375 0 0 64 630 52 43 2.000 6.068 3.517 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10/02 12:30:00 135.9 20.000 2375 0 0 65 630 52 44 2.000 6.059 3.643 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10/02 13:00:00 136.4 20.000 2375 0 0 66 615 50 40 2.000 5.897 3.768 0 11.7 100 0 0 0 0 0 0 0 11.7 0 0.0 04/10/02 13:30:00 136.9 20.000 2375 0 0 66 600 53 44 2.000 5.950 3.891 0 13.8 100 0 0 0 0 0 0 2.1 13.8 100.8 0.0 04/10/02 14:00:00 137.4 20.000 2375 0 0 66 600 53 44 2.000 5.950 4.015 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10/02 14:30:00 137.9 20.000 2380 0 0 67 600 53 44 2.000 5.950 4.139 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10/02 15:00:00 138.4 20.000 2380 0 0 67 615 51 40 2.000 5.956 4.263 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10102 15:30:00 138.9 20.000 2380 0 0 67 620 49 38 2.000 5.884 4.386 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10102 15:50:00 139.3 R&K heater off location-not repairat 0 67 620 49 38 2.000 5.884 4.468 0 13.8 100 0 0 0 0 0 01 0 13.8 0 0.0 04/10102 16:00:00 139.4 20.000 2380 0 0 67 620 51 40 2.000 5.984 4.509 0 13.8 100 0 0 0 0 0 01 0 13.8 0 0.0 04/10102 16:30:00 139.9 2380 0 0 67 620 49 38 2.000 5.884 4.632 0 13.8 100 0 0 0 0 0 0) 0 13.8 0 0.0 04/10/02 17:00:00 140.4 2380 0 0 68 615 51 34 2.000 6.014 4.756 0 13.8 100 0 0 0 0 0 01 0 13.8 0 0.0 04/10/02 17:13:00 140.6 Open choke to 22/{ 2320 0 0 67 620 60 36 2.000 6.532 4.813 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10102 17:30:00 140.9 2300 0 0 67 620 60 36 2.000 6.532 4.890 0 13.8 100 0 0 0 0 0 0 0 13.8 0 0.0 04/10/02 17:30:00 140.9 22.000 2300 0 0 67 620 60 36 2.000 6.532 4.890 0 13.8 100 0 0 0 0 0 0' 0 13.8 0 0.0 04/10102 18:00:00 141.4 22.000 2300 0 0 70 600 63 32 2.000 6.612 5.027 0 15.1 100 0 0 0 0 0 0 1.3 15.1 62.4 0.0 04/10102 18:30:00 141.9 22.000 2300 0 0 70 600 66 34 2.000 6.745 5.166 0 16.4 100 0 0 0 0 0 0 1.3 16.4 62.4 0.0 04/10/02 19:00:00 142.4 22.000 2300 0 0 70 575 68 32 2.000 6.704 5.306 0 16.8 100 0 0 0 0 0 0 0.4 16.8 19.2 0.0 04/10/02 19:15:00 142.7 22.000 2300 0 0 70 570 70 30 2.000 6.790 5.377 0 17.2 100 0 0 0 0 0 0 0.4 17.2 38.4 0.0 04/10/02 19:16:00 142.7 Shut well in & man iter pressure with spider 04/10/02 21:00:00 144.4 Open to manifold to record S.I.P. 04/10/02 21 :00:00 144.4 2900 04/10/02 22:00:00 145.4 2900 04/10102 23:00:00 146.4 2900 04/11/02 0:00:00 147.4 2900 04/11/02 0:01:00 147.4 2910 04/11/02 0:02:00 147.5 2910 04/11/02 0:03:00 147.5 2910 04/11/02 0:04:00 147.5 2910 04/11/02 0:05:00 147.5 2910 04/11/02 0:06:00 147.5 2910 Prepared by pts 4/19/2002 Page 3 MARATHON OIL COMPANY DATE: PBTD: WORK DONE: FILL DEPTH/DATE: OTH ER: 5/8/2002 SUMMARY OF OPERATIONS ) ) DAILY WELL OPERATIONS REPORT FIELD: 8809' MD (WLM) LINER: Set backpressure valve in tubing hanger Initial Completion Padlocked closed master valves. Wildcat NIA CASING: TREE CONDITION: CREW: Hrs. PAGE 1 OF 1 WELL #: Falls Creek #1 RD 4-1/2",12.6 #,L-80 new New 4-1/16", 5K w/4" Bowen cap ABB Vetco 3 RU Vetco to lubricate backpressure valve into tubing hanger. Set backpressure valve. Performed negative test on backpressure 8:00 valve. Valve held ok. 10:00 RDMO ABB Vetco. Vendor DAILY COST: Equipment $0.00 $0.00 CUM: Daily Cost REPORTED BY: Cumulative Cost Ken Walsh Jun-20-02 08 :45am F rcm-MARATHO~' +9155646489 T-S45 P.Ol F-S84 Alaska Region Domestic: Production M MARATHON t. ........::, ... -~ Marathon Oil Company P.o. Box 196168 Anchor~ge, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 June 20,2002 Steve McMain AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. McMain: Please find faxed with this cover letter~ a copy of McLane's SUlVeying report for the proper offset information for the Falls Creek #1 original well bore and the Falls Creek #1 RD sidetrack located in the Falls Creek Unjt. The proper offset for the identical surface location of these two wells is as follows: 1898S FSL, 2885' FEL, Section 6, T1 N, R12W, S.M. Also faxed, is a copy of the directional survey for the Falls Creek #1 RD per your request. You will note on the 10-407 submitted for this well's completion on 04/22/02 that the location data for the top of the producing interval at 7850' MD is correct at 1821' FSL, 5013' FEL, Sec. 6, T1 N, R12W SM. The offset data at the 8900' MD TD is not correct due to a typographical error in the EIW description. The correct offset at TD should read 1830' FSL, 5025' FEL, Sec. 6, T1 N, R12W SM. A 10-407 page #1 which includes the offset TD correction for the Falls Creek #1 RD has also been included with this cover letter. Please accept our apologies for any confusion associated with this matter. If you would like any other information, please contact me at 564-6305 or kdwalsh@ marathonoil.com. Sincerely, I~ ~W~ Ken D. Walsh Advanced Production Engineer RECEIVED JUN 2 0 2002 Alaska Oil & Gas Cons. Commission And1cIage :....,..,.H(~.q"......:-~~~.....~)i...41..~~~1I .-- -".,...,- -1IfI.~A.-·· 1 i ill _ WA TEf< WEL-L (TYP.) røÞ UJ z - -l >- æ It ~ {L 248.t3 _,. I __ I ....... ... U 'f ...... ..., -----. 24~~.___.... "-."'--.. .~'" , ..,-..... ca4,S' 248-8 ,/ :;¡4~2. __ _'·w _ .., , FALL5 CREEK NO~ 1 1S~8J F5L 268&1 FEL SECTION 6 T1N, R12U.J,5~M., AK N 22694SØ~2 E :2.3~S4ØJ ~ .-..... . ~ '--' -.... . " F-884 T-845 P.02 ) +9155646489 Jun-20-02 08:45am . From-MARATHON ) ft. "". , ,../1 -"IiI1..;, 4Æ).' J' .', '-"-" Jun-2C-02 08:45am From-MARATHON +9155646489 ) T-345 P.03/09 F-384 .:.. ~ Survey Report ,,,.,,..I'tN{Ir'-;"""",''''I'I''!I' II' "1 , .--.-'-.... ,..·..p...,·IWIfII"'M·".,··I''''''I'il'l' I . ,..¡. I' 1" 1\" I" I" , .,. I' I ::ëomp"~Y;:','M~rå~I:1~~'Qil.~'Omp~/'IY :'> " ,': ",":, '" -: D~~~~," ~~f2Q02'>,::::, ,Ti~e:: :13:3~:10,,:',; ,:::'~,;:,:,: :'r~~~:': ,:':,:.'':::' ,; 'Field::':" :' F~II$:Qr~aK: ': :: " , ",',:: '" , " ':': ',: :: ,,,: ':' ':' :" CO-Qr.din3t~(NJi\H~,~f~r~nç~;:' : ': :""81': Falls Cree~'~1. True North:": !',:: :.' ':, " ':: Site: :": ';:' '-:, F:.~l1s:çreelt:röc~tio~,,' ': "<:': ,:," ":"" ":,,: " ::: ' :: '::' , ,> : VQrtiç~nl'VJn 'fWfér,,,,ëc':::, ':, :,'>C4rrent.:DrI'mr19:266~Q::,::: : ,:::-:; ';" '::, "::,: ': :,,::: ': Wc)J; ::::,-: ::;: F:~lIs qreek;~1'~':" , , ,..;" :, '" ':...; , < :: : ; ,::' , :: ", ,'! Section (yS) Reference:;,' ': ", ,:: : Well (b':ÖON;0.Q05;27Ö;OÖ~if :' ': :: , :.': :,:' ,; .i.:.'Y.~~~P..~t~.~:~_~i~et~~~::" :: : :, " , :' , :: " " " "', ,,:,:: .:.:_'._~'_,: '. :.~~~ ' ~"...:_,:,.,:'" ,n 'n ~.~_~.i.~unicY 9aJcl~},lItion ~e~hð~; :", ,:":Mi~im:um þurvatüre; ::::: '," ',:Db:' .. ,:S'Yba~W~::...,. Field; Fal15 Crl¡ll¡lK USA Map Sysum;US State Plana Coordinate System 1927 GI!Q Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map ZOfle: Coordinate SYllitem: Geomagneric MOGel; AlasKa, ZOM 4 Well Centre Wmm_95 ."_,._,_,.. -- ----- ----..---.. Sit~~ Falls Creek location Sët::, 8, T1N, R12W, Kenai Borough SU'!!, Position: NOl1hir\g: 22ß94!50.20 ft ¡"rOm: Map Essting: 239940.10 ft PC)sition Uncertainty: 0.00 ft Cround level; 0.00 ft Latitude: Longit\lde; North Rmcrcnce: Grid COßvergenc:c; 60 12 15.857 N 151 25 4ftS22 W True _ ~~.:24...~~~ -.---" -.--- ... ., .-..--..-- W~II: Falls Creek #1 Slot Name: Wen PosJtion: -rN/-S +.£I-w PositiOn tf öc:ert¡\il\ty: 0.00 ft Northing: 226!i1450.20 ft Latitude: 0,00 ft Ji:a:$tb1g ~ 2~9940.10 1\ Longitude~ 0.00 ft 60 12 15.857 N 151 25 46.322 W __, --.... _,-,." ,,'.--- Wellpllth; Sidetrack Sidetrack to regain productive interval Current Datum: Current Drillin!;l Hei1:ht Magnetic Data: 819/2001 Fie1d Str~.,gth: 55079 nT Vertical Section: Depth From (TVD) ft 0.00 266.00 ft Drilled From: Tie-on Depth: AbOve Sysrtlñ D~tlu"": P,clhu-.Uop: Mal:: Dip Angle: +£I-W ft 0.00 Original Wellbore 3150,00 ft Mean $aa !-aval 21.05 deg 73.23 deg Direçdon ..~!~- 270.00 +N/-S ft 0.00 ...~ .._,;..."",,"'., Survey Program for D~fiqiti\'e Wellpath Date: 2/SI2002 Validi\t'td; No A~tual From To Survey tt ft 1095.22 8900.00 Gyro Survey of Sidetrack Venion: 2 T~..I~~d, Tool Name ~--- --....... ..." -..... .n __._. . . _. !'JS Gy!....o Survey ., ",..~".I'''.,,':.'::.''':,,: ':I',·I!"·\·\O", . 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"'" ...". '" ..---:"'-~;':";'~":"."'~"''''~,':'''';,';;w;;o/rrf'I't"I~''''''~'..''',I''' 'II I II'.I~ 11111'11 :'. I~'I., I,,, .... .,. ': . :.:: : M.D:.:::: : Inel. :. :.: . A~I,"' , . .. :rVD .... t~l-S +~- w ; , vs· .... . Dl.S.. . Judd . ;TurlJ TOOI/COmmclJt.. ,: : . ,,:. ... .... ,: '.:':.~ ::~:;::::. :: .. .~ét,-.: ... .. ~~~.:.:._:.~..~_~;.~>:~ ,.: ,:;" ,. : .:ft :.;.:',. ~.::-:. : .' ft:' :. deg/100ft ~eg/1,ÒOfÙle9/1QO~ :. :. ":: ..;',:'::"':. 17S6.5.2 12.56 238.10 1783.55 ..24.55 -37.07 37,07 4,80 4.55 7.41 NS Gyro 1817.94 13.81 241,52 1614.14 -2S.14 -43,47 43.27 4.6S ~.98 10.88 NS GytO 1 e49.35 1880,78 1912,21 1943.53 1975.05 2006.47 2037.90 2069.:32 2100.74 2132,16 2163.59 2195,01 2~2ß.43 2257,85 2289.28 2320,70 2352.12 2383.54 2414.97 2446.39 2477.81 2509.23 2540.66 2572.08 2603.5Q 2634.92 2666.35 2697.77 2729.19 2760.61 2792.04 2823.46 2854.88 2886.30 2917.73 2949.15 2980,57 3011.99 3043.42 3074,84 3106.26 3137.68 3169.11 3~00.53 3231.95 3263.37 32!:l4.S0 3326.22 3357.64 3389.06 3420.49 15.07 16.14 16.69 1tleo 16.95 16.82 16.67 16.70 16.81 16.57 16.35 16,36 16.38 16,38 16.42 16.33 16.12 15.91 15.72 15.94 16.41 16.81 17.21 17.52 17.71 17.99 18.39 18.20 17.40 16.74 16.72 17.4::; 18.47 18.58 18,50 18,30 17,67 17.56 17.48 16.90 20.50 .23.05 23.98 25.45 27.26 28.91 30.40 31.68 32.59 33.45 34.05 241.53 241.21 241.46 241.75 241 .62 242.11 241.34 241.46 241,40 242.01 241,90 242.17 242.28 242,62 242.82 242.94 242,47 242,36 243.15 243,1a 242.73 242.93 242.50 241.92 240.95 241.14 241.09 242.52 245.44 .250.07 255.71 259.94 262.85 263.39 263.13 263.25 263.3; 263.43 264.02 265.4'7 266.31 266.19 266.57 266.90 26t:L83 267.28 268.23 269.01 268.63 271.41 1844.57 1874.83 1904.98 1935,06 1965,12 1995,18 20.25.28 2055.38 2085.46 2115.56 2145.70 2175.85 2206.00 :2236.14 2266.29 2296.44 2326.61 2356.81 2387.05 2417.28 2447.45 2477.55 2507.62 2537.60 2567.55 2597.46 2627.32 2657.15 2667.07 2717.10 2747.20 2777.24 2807.13 2836,92 2866.72 2896.53 2926.42 2956.36 2986.32 3016.17 3045.75 3074.92 3103.74 3132.2B 3160.44 3188.15 3215.47 3242.39 3268.99 3295.34 272,43 3321.47 .... " , '.. I."" ',' ,,' .. ..,'I,' ,..' " , .. .. . : Ðate: ;. 4/3/2002: ..::,: Tilne: ,13:34: 1 a:·: . " ::" " '.: :' .' ..:: "Pl\ge: ;"', , ::. ;,2,:; ...,::' . ", Có-orIJi"1\tc'(l\1I}) ~Bfcr~"~'B:'" :.,' 'W')II~:f~lIç'Oré(¡JK:#1 :Tf'~Q NQfl~ I',: I, :: : I I:' ; :', ..' ::: :.:.:....: ~&:rticKl (TV») R.crèré~ec:· ;.:-,: ,: ::Current Drlllfng' 266,0:... .. ',:, ...;:: ,'::: :.: '::::::. ..::: ":':;':'::.. :. Section (VS) Reference: .: ,: :.: :,:: ·:Well:(d,.OQN;O.doE;210~ÖÓAZif:::: :.::':.:: ; ':.:',: .: ::: . :. :.:" . : ': ~"fV~Ÿ. Ç.~&;~1~iiori M'othøiJ(, :;:: Mh,im'um CÙn;~~Ui'å :: ....-:..: . :Pþ:;, ; $yÞa'~.e r : :: ____.1_' "I.."" .n,",,,·, "," ,." . ·P,,"'., ,,,, ....".... ................0111...1..._.". r."._.. ...... "_._..............~..v,,r .. .r"··_,, ,', ."... ..,.."", " " '",''' .,. I., I,,, 1t,"MII'I'.,..',.,..... , .. n. ,......,..._._... w31.87 -:35.93 -40.19 44.50 -48.84 -53.14 -5'1.43 ..61.75 -66.08 -70.M -74.55 -78.70 w82.82 -86.92 ..90.99 ..95.03 -99.05 -103.Q7 -106,99 -110.SB -114.54 -118.94 ·123.15 -127,53 -132.07 ~136,74 -141.4B ·146,14 -150.35 ·153.85 -156.51 ·158.45 -159.S9 ·161.06 -162.26 -16~.4~ -164.56 -165.66 -166.70 -167.59 -168.35 w169.11 ·169.90 -1;0.85 -171.41 ~172.17 -172.17 ·173,16 -173.51 -173.50 -172.91 ..50.15 -õ7.57 -65.37 ..73.35 -81.4Q -69.45 -97.43 ·105.35 -11$.30 -121.25 -1 :29.11 ..136.92 -144.76 -152.61 ~160.50 ·168.38 -176.18 ·183.87 -191.48 -199.13 -20a.93 ·214.92 ~223.0S -231.36 -239. '73 -246.16 -256. i5 ·265.44 -274.07 ·282,60 ·291.23 -300,25 -309.83 -319.74 ~329.67 -339.51 -349.15 -358.62 -368.05 ..377.8'2 -388.38 -400.01 412.53 -425.64 -439.!;s7 -454.35 -469.89 -486.08 -502,79 -519.91 50.15 67.57 65.37 73.35 81.40 89.45 97.43 105.35 11$.30 121.25 129.11 136.92 144.76 152.61 160.50 168.36 176.16 183.87 191.48 199.13 206.93 214,92 223,09 231,38 239.'73 248,16 256.75 265.44 274.07 2S2.60 291.23 300.25 309.83 319.74 329.67 339.51 349.15 358.62 368.05 377.82 388.38 400.01 412.53 425,64 439.57 454.35 469.89 486.08 502.79 519.91 --- ·537.36 537.36 4.01 3.42 1.76 0.72 0..20 0.61 0.65 0.15 0.35 0.95 -0.41 ·0.48 0.10 0.35 ·0.76 -0.70 0.03 0.06 0.00 0.13 -0.29 -0.67 -0.67 -0.60 0.70 1.50 1.27 1.27 0.99 0.60 0.89 1.27 -0.60 ·2.55 -2.10 0.71 0,24 0.12 0.31 0.22 0.31 0.79 0.68 0.91 0.70 1.55 1.29 1.33 1.13 1.11 0.91 1.27 1.55 3.81 4.81 5.16 4.59 4.32 0.65 0.37 0,65 2.01 0,07 0,61 4.74 -0.06 2.32 3.25 0.35 -0.25 -0.64 ·2.01 -0.03 -0.67 4,52 5,17 8.12 3.00 4.70 5.83 5.23 4.97 4.27 2.97 5.54 2.63 1.91 ---.. 4.01 3.41 1.75 0.67 0.16 0.03 -1.02 0,80 0.92 -0.41 1.56 ·2.45 0.38 -0.19 1.94 -0.35 0.86 0.35 1.08 0.64 0.:38 -1.50 -0.35 2.51 0.10 ·1.43 0.64 -1.37' -1.85 ·3.09 0.60 -0.16 4.55 9.29 14.74 17.94 13.46 9.26 1.72 -0.83 5.09 8.12 2.96 4.68 5.82 5.19 4.74 4.07 2.90 2.74 0.38 0.38 0.19 1.88 4.61 2.67' ..0.36 1,21 1.05 -0.22 1.43 3.02 2.48 -1.21 8.85 3.25 NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS GytO NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS GytO NS Gyro NS Gyro NS Gyro NS GytO NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gym NS Gym NS Gyro NS Gy(O NS Gyro NS Gyro NS Gyro .. _.¥ Jun-20-02 08:45am From-MARATHON '"........_..........''' n.., +9155646489 Survey Report ,çomp.~~;~ : ~a~~h6n: Oil :pö~pä~y ',Field:' :, , ':; Falls Creek' , " " ':Š1fe: :, :, ::: :: :', ,: f.all~' C'reeldgcåtion:: , : ':W~..; : ': , : F~lIs c;reek'#1:" , " " '" ,WéU,lJH,tl:l=:: Si~e~f.8c~: ': ," ':" ': ,: :::: " , S..-rny ': 'MQ :,< ,:":, ~-;~~'~~,irri"::":""""''':':''::'':rVD::'::''::'':''::'''':';:NI~s~~',.'" , .._ :' ~' , ..; ,: " , :: de.~r ',::, > ': deg " , : ": ' : ft; " : ' , ::- ' ' , :ft 3451.91 35.27 273.21 3347.32 -172.03 3483.33 36.80 274,09 S372.72 -1;0.85 3614.75 38.25 274.59 3397.64 -169.40 354ß.18 39.84 274.39 3422.05 ..167.85 3577 .60 3609.02 3640.44 3671.87 370~.29 3734.71 3766.13 3797.56 3828.98 3860.40 3891.82 3923.25 3954.67 3986.09 4017.51 4048.94 40130.36 4111.;8 4143.20 4174.63 4206.05 4237.47 4268.89 4300.:32 4331.74 4363.16 4394.58 4426.01 4457.43 4488.85 4520.27 4551.70 4583.12 4614.54 4645.96 4677.39 4708.81 4740.23 4771.65 4803.08 4834.50 4865.92 4897.34 4928.77 4960.19 4991.61 5023.03 5054.46 5085.88 5117.30 41.38 42.70 42.96 43.12 4~.48 43.72 44.14 44.66 44.90 45.18 45.43 45.51 44.38 43.79 44.16 44.43 43.10 41.71 42.12 42.31 42,57 42.81 42.81 43,13 43.06 43.20 43.00 42.61 41.59 40.58 39.22 38.91 38.95 39.10 37.86 37.76 36.66 36.29 35.46 35.48 35.76 35.61 34.40 ~3.62 32.71 32.30 32.36 32.03 31.30 31.03 274.90 275.78 276.06 276.46 2'15.88 275.89 276.17 276.66 276.48 277.16 276.41 216.57 277 .82 277.38 277.92 277,78 277.85 278.89 ~78.20 277.08 277.80 277.18 277 .52 277.83 278.09 278.55 276.64 278.32 276.55 275.94- 275.48 275.85 274.96 274.97 274.30 273.00 273.24 273.06 271.62 271.26 271.56 270.06 271 .44 271.99 :l72.48 273.53 273.23 273.38 272.69 272.46 ) T-345 P.05/09 F-384 , I I' I' , , ,'1'.... . " I I ',.. I I' '" "I.,,,,,, '" , ' " ; D¡ltc; '4~3!?a.q2,~" ,,::' ,! "time::.' ,1~¡34:'19:: :'.: "::'; ,:: ': " ",P~gJ!:." :: ':',3,: ':: ::-" :; , : : ; ; ,: ' '" :,,' ," ': CO-l>rdil1.-te.(NE):Referellce:"', :' Well;, Falls Crøek'#1 ;:,Tr.ue';Ncrth ,,,,',,'," , ,',":: , " ,:' '" '" : V~nìc'~J(lYPHwf~r.ó~çe; " , :: CU'rrénfOrllll~9 ~~6:.Q,: :: ; :: ,: ,;::;, ,<>:::;:;' ::; :, :,' " "" " " , '" ',Sectio'n (VS) 'R'el'ereiJcë~:: ", ': Well (O::OON~O OOE..270.'OOAzI)' !" ','" ': ': ' ': ' :' : ' ': ' , : Surv~ Caicui~tion Method: ,: :: " : 'Min¡~'uni dt.l~at.Ure ,';',':::: Db:;' :,SŸbäse,:: ,: " 3445.90 3469.24 3492.28 3515.25 3538.12 3560.67 3583.50 3605.96 3628.26 3650.46 3672.56 3694.60 3716.64 3739.41 3762.02 ~;84.51 3807.21 3830.41 385:3.7'9 3877.06 3900.25 3923.35 3946.40 3969.39 3992.34 4015.27 4038.21 4061.27 40134.58 4108.27 4132.:37 4156.77 4181.22 4205.63 4230.22 4255.05 4280.08 4305.34 4330.80 4356.40 4381.94 4407.46 4433.20 4459.25 4485.55 4512.05 4538.60 4665,20 4591.94 4618.82 '. ... -166.19 -164.23 ..162.03 -159.69 -157.38 -155.15 -152.66 -150.41 -147.67 -145.23 -142.60 ..140.Q6 -137.2~ -134.39 ..131.49 ',:¡:~/-W " ,1'1, -555.21 -573.65 -592.74 ·612.47 -632.86 -653.60 ~675.05 -696.:37 M717.60 -739.35 -761.02 -782.68 -804.67 ·826.94 -849.12 ·871.38 -89:3.40 -915.07 -936.69 -128.49 -958.44 -125.54 -979.97 -122.46 -1000.9~ -119.34 ·1021.69 ~116.53 -1042.62 -113.78 -1063.64 -111.01 -1064.76 -108.28 -1105.94 -105.41 ~1127.17 -102.44 -1148.43 -99.33 -1169.68 -96.50 -1190.96 -93.72 ~1212.14 -90.99 -1233.02 -88.74 -1253.55 -86.73 -1273.60 -84.78 -1293.31 -82.92 -1312.97 -81.21 -1332.67 -7'9.63 -1352.16 -78.4,0 -1371.39 -77.37 -1390.36 ·76.34 ~1409.01 -75.59 -1427.41 -75.13 ·1445.64 ·74.68 ~1463.a3 -74.42 -1482.26 ·74.18 -1500.26 -73.66 -1517.85 -72.99 ~1535.03 -72.11 -1551.89 -71.12 -1568.66 -70.15 -1585.38 -69.28 -1801.85 -68.54 -16113.09 , I I . ,: VS,':';,'; "OLS : :,Build:, ,:Turn ,,' Tool/Commenl' :'; ,,' , " " 11;: ,::::': deg/100ft,i:låg/100f(i:løgI.100ft",:,:' ::':':.'::, ,: :,:: ,: :':: ::, ,', ',: ;'.' " 555.21 4.13 3.86 2,48 NS GyfO 573.65 5.14 4.87 2.80 NS Gyro 592.74 4.72 4.61 1.59 NS Gyro 612,47 5.07 5,06 -0.64 NS Gyro 632.86 653.80 e75.05 696.37 717.80 739.35 761.0:3 782.86 804.87 826.94 649.12 671.36 893.40 915.07 936.69 958.44 979.97 1 OOO.9~ 1021.69 1042.62 1063.64 1084.76 1105.94 1127.17 1148.43 1169.68 1190.96 1212.14 1233.02 1253.55 1273.60 1293.31 1312.97 1332.6; 1352.16 1371.39 1390.36 1409.01 1427.41 1445.64 1463.93 1482.26 1500.28 1517.85 1535.03 1551.89 1568.66 1585.38 1601.85 1618.09 5.01 4.60 1.03 1.01 1.71 0.76 1.47 1.98 0.86 1.77 1.87 0.44 4.56 2.12 1.68 0.91 4.24 4.96 1.96 2.47 1.75 1.54 0.74 1.22 0.61 1.10 4.20 3.84 4.98 3.46 4.43 1.23 1.78 0.48 4.16 2,56 ~.53 1.23 3.77 0.67 1.05 2.83 4.60 2.67 3.02 2.22 0.55 1.06 2.59 0.94 4.90 4.20 0.83 0.51 1.15 0.76 1.34 1.65 0.76 0.89 0.80 0.25 -3.60 ..1.8S 1.18 0.66 -4,23 -4.42 1.30 0.60 0,83 0.16 0.00 1.02 -0.22 0.45 -0.64 -1.24 -3.25 -~.21 -4.33 -0.99 0.13 0.48 -3.95 ~0.32 -3.50 -1.18 -2.54 0.06 0.89 -0.48 -3.85 -2.48 -2.90 -1.30 0.19 -1.05 -2.32 -0.86 1.62 2.80 0.89 1.27 -1,85 0.03 0.89 1.56 -0.57 2.16 -2.39 0.51 3.98 -1,40 1.;2 -0.45 0.22 3.31 -2.20 -3.56 2.29 -1 .97 1.08 0.99 0.83 1.46 -6.08 5.35 ·5.63 -1.94 -1.46 1.18 -2.8~ 0.03 -2.1~ -4.14 0.76 -0.57 -4.58 -1.15 0.95 -4.77 4.39 1.75 1.56 3.34 -0.95 0.48 -2.20 -0.7$ NS Gyro N$ Gyro NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gym NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro !\IS Gyro NS Gyro NS Gyro NS Gyro NS GyI'Q NS GyI'Q NS Gyro NS Gyro NS Gyro NS Gyro NS GYfO NS Gyro !\IS Gyl'O NS Gyro NS Gyro NS Gym NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyre NSGyro NS Gyro NS Gyro .. Jun-20-02 08:45am ., From-MARATHON"" I., , Survey Report +9155646489 I) T-345 P.06/09 F-384 .,',,··"......~."".."II'...II"I".,.'.. " ':: ë)':"padY:: : ; Maråthöï1 :Oil: öör1itlåM: :. :' : :. , , :::r..ø.~~ '. ,,' . Falls Creek ":':' :. :' . ':"': .:' , ::'. , . :5~~~: j~~~~.~r,·.. ;';:':....... ... :.i: . .. . .., ,. .. ,. ''''''-''''~I'""""","'''~''',",IT,"""",''I''ffI'I'~~ . , , .DlIle;: 4/3120Q2>'. :: :. Time~: 13'34'·10' '.: .' '.' , .:" ' : "";Pagë~' :..:: . ::,V: ',,; :.. .' . ... C6~Ð~~lnatt(NED:~~fer~nç~;:· "Wt¡t;·~~,is:q;räek:#.1 ,:ir~:~:N(jrth > ::::'.:::. :::~: .~,':, -: ::' '.: ~ci1;'c·d:n·V.ß) R~fc"eQco::,:-:' .; :C~rr~nt DrI1lltlg.,266;O:.::·, ,::::!"~';,,':: -:::. :'..:.:::-,.::::' . . .'. S,ech()n (VS):RcfereD;~e: ' :" :" ,'Well (0.OON~O.OOE;270~00~1):.:: :::: .::.,:" :, :. Sutve:y'CalcuJation.Metbod: . .: Miriirril.im C~rvati.ire: .; :.:. '. ·.Qb:L~b;;\i~:~L~.,~~ Survey ----··-"1'\\'.,·"..·'·'''11''''''''1'''1'11'''''11'1'''1.'., " ,. ~p,,, . lucl ,·Azim:: '. ;,: ::." :TVD ;: :, :"t'N/-S 2j.:~:.~.¡"..! ..:}.~::.~~~.:;:: :':::;: :d~g,,: :-'::.::', (f' ,,' : . :. ·ff 5148.72 5160,15 5211.57 5242.99 5274.41 5305.84 5:337.26 5368.68 5400.10 5431.53 5462.95 5494.37 5525.79 5549.26 5557.22 5586.64 5620.06 5651.48 5682,91 5714.33 5745,75 57'77.17 5808.60 5840.02 5871.44 5902.86 5934.29 5965.71 5997.13 6028.56 6059.96 8091.40 6122.62 6154.24 6185.67 6217,09 6248.51 6279,93 6311.36 6342,78 6374.20 6405.62 6437.05 6468,47 6499,89 13531.31 6562.74 6594.16 6625.58 6657.00 6688.43 6719.85 6751.27 30.26 30.16 28.93 28.72 27.60 27,14 25.74 25.12 24.12 23.72 22.60 22.44 22.33 21.93 21.79 20.76 20.38 19.80 19.34 18.57 17.99 17.22 16.51 15.60 15.66 15.69 15,55 15.:n 14,61 14.82 13,56 1 3.40 13.09 12.21 12.07 11.95 11.41 10.18 9.50 9.12 9.08 9.09 8.83 7.69 7.4S 7.66 7.42 6.31 5.72 5.57 5.45 5.46 5.54 271.89 271.85 269.68 270.38 269.53 270.61 269.82 269.51 270.08 269,89 269.85 270.31 268.50 269.16 269.39 287.70 267.67 268.16 268.74 268.21 268.21 267,33 266,94 266.79 267,65 268.23 266.86 269.75 269.98 269.72 271.68 271.34 271.06 269.56 270.30 270.60 269.99 268.43 268.39 268.31 269.85 269.11 269.47 266.95 268.67 269,66 270.81 270,78 271.65 273.86 275.59 279.27 260.70 4645.86 4673,02 4700.35 4727.88 4755.58 4.,83.49 4811.62 4840.00 4868.56 4697.29 4926.16 4955.21 4984.26 5ooa.00 5013.39 5042.67 5072.08 5101.59 5131.21 5160.92 5190.76 5220.70 5250.78 5280.98 5311.23 5341.49 5371.75 5402.04 5432.37 5462.75 5493.22 5523.78 5554.36 5585.02 5615.74 5646.48 5677.25 5708.11 5739.08 5770.08 5801.11 5832.13 5863.16 5894.27 5925.42 5956.66 5987.72 6018.92 6050.15 6081.43 6112.72 6143.99 6175.27 ... +FJft~ . ..... ':: ,~~1f~J'.;~~i~Tt~l~}: ., .. -67.94 -1634.10 ·67.42 ·1649.90 -67.21 -1665.39 -67.20 ·1680.54 ~67.21 -1695.37 -67.19 -1709.82 -67.14 -1723,81 -67.22 -1137.30 ·67.26 ·1750,39 -67.27 -1762.13 -67.30 -117'5.49 ·67.28 -1787.52 -67.40 -1799.49 -67.58 -1808.32 -67.62 -1811.29 -67.91 -1822.68 -68.35 -1833.71 -6a.i5 -1844.50 ..69.03 -1855,02 -69.30 -1865,22 ·69.61 -1875.08 -69,98 -1884.57 -70.43 -1893.68 ..70.91 -1902.35 -71.3~ -1910.81 ,,71.62 ·1919.29 -71.M -1927.75 -71.94 -1936.13 -71.96 -1944.31 -71.98 -1952.34 ..71.89 -1960.04 -71,70 -1967.~7 -71.55 -1974.56 -71.51 ·1981.44 -71,52 -1988.05 -71.47 ,,1994.59 -71.43 -2000.95 ·71.51 ~2006.83 -71.66 -2012.20 ·71.80 ·2017.28 -71.88 -2022.25 -71.93 ·2027,21 -71.98 -2032.11 -72.12 ·2036,62 -72,28 -2040.76 -72.34 -2044.90 -72.32 ·2049.03 -72.27 -2052.78 ·72.20 -2056.07 ·72.05 -2059.16 -71.80 -2062.17 -71.42 -2065.13 -70.90 -2008,09 1634.10 1649.90 1665.39 1680.54 1695.37 1709.82 1723.81 1737.30 1750.39 1763.13 1775.49 1787.52 179a.49 1808.32 1811.29 1822.68 1833.71 1844.50 1855.02 1865.2~ 1875.08 1884.57 1893.68 1902.35 1910.81 1919.29 1927.75 1936.13 1944.31 1952.34 1960.04 1967.31 1974.56 1981.44 1988.05 1994.59 2000.95 ~006.63 2012.20 2017.28 2022.25 2027.21 2032.11 2036.62 2040.76 2044.90 2049.0~ 2052.76 2056.07 2059.16 2062.17 2065.13 2066.09 2.62 0.32 5.19 1.27 3.79 2.15 4.59 2.02 3.27 1.30 3.56 0.76 2.42 2.02 2.02 3.61 1.21 1.92 1.59 2.51 1.85 2.59 2.29 2.90 0.76 0.51 0.70 0.95 1.79 0.21 4.29 0.57 1.01 2.99 0.67 0.43 1,76 4.02 2.16 1,21 0,79 O.M 0.84 3.81 0.98 -2.45 -0.32 -3.91 -0.67 -~.56 -1.46 -4.46 -1.97 -3.18 -1.27 -3.56 -0.51 -0.35 -1.72 -1.71 -3.26 -1.21 -1.85 -1.46 -2.45 -1.85 -2.45 -2.26 -2.90 0.19 0.10 -0.45 -0.57 n1.76 0.03 -4.01 -0.51 -0,99 -2.80 -0.45 ·0.38 "1,72 -3.91 -2.16 -1.21 -0.13 0.03 -0.83 -3.63 -0.67 0.71 0.90 3.53 1.90 0.84 0.65 1,11 0.51 -1.81 -0.13 -6.91 2.23 -2.71 3.44 -2.51 -0.99 1.81 -0.60 -0.13 1.46 -5.16 2,81 2.88 ·5.38 -0.10 1.56 1.65 -1.69 0.00 -2.80 -1.24 -0.48 2.74 1.85 2.00 2.83 0.73 -0.83 6.24 -1,08 -0.89 -4.77 2,35 0,95 -1.94 -4.96 -0.13 -0.25 4,90 ·2.16 0.95 -8.02 5.4" 0.57 .0.76 -3.53 -1.88 -O.4S ·0.38 0,03 0.25 3.21 3.60 -0.10 2.77 7.03 5.50 11.71 4,55 . ". . ". "" NS Gyro NS ~yto NS Gyro NS GyI"Q NS Gyro NS Gyro NS ~yro NS Gyro NS ~yto NS Gyro NS Gyro NS Gyro NSGyro Target 1 NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS ~yro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyf'Q NS Gyro NS Gyro N$ Gyro NS Gym NS Gyro NS Gyro NS ~y'I'O NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro Jun-2C-02 08:46am ~,""....._....".,_. .....-..,.., . .. From-MARATHON ) --... -.-- -. Survey Report .--.-.. ---- .... -- .--_..-- . +9155646489 ) T-345 p.Or/09 F-384 " ,. I "". , "", I"" " " ., .. ,I' . '" """ ,,,...,,,.... , ': ' :: ,: : b¡lte::, ~/~!?9.o.~:: ,-: :,':::: ';~i~ø,: ,: :13:3~:~:0 ': ,:'..:" ':,::,: ::' > :,:~~r;~::' ,:": ',::5, :: , :' "', ,: ': Co.ordiöar.e(NE) 'Reference;: : :: Well: Falls' Creek #1 ~::'frue North,', ,':" ' ": ':: ,,,' , ",::':' ': : "Vtr1lë"nTVÞ> Refe:ren(ë~ :: :': Currerit'DrillÎna 266 0;': ,:" ::': ';': "', ,':': ,:'::' , :: , ' : ':: ':,." Sc~~~n (yS) ,~fer~n'cë(:,~ '::,::: ~ell'(0.OOt'l.p:OOe.:27;Ö"O:ÖÄ.t:i>:' :: : :,:':' :~': ::: " , " ':',', Survey Ca}cu}a1ion'Method:: ;,'::: Minir:IlI.Im Curvature,!':' ':, Db: ,Sybae.e , .... . ,...t " ... " I I .~¥lj[$~~~r:!..!:¡..:·...:.:::·.:.:'..:···· SloItveY' :,:':::,:;~:'~¡::: 6782.69 61314.12 6845.54- 6876.96 6908.38 6939.81 a971.2S 7002.156 7034.07 7066.49 7096.92 7128.34 7159.76 7191.18 7222.61 7254.03 7285.45 7316,87 7348,30 7379.72 7411,14 7442.5S 7473.99 7505,41 7536.83 7568.25 7599.68 7E!:;1.10 7662.52 7693.94 n25.~7 7756.79 7788.21 7819.63 . 7851.Q6 7882.48 7913.90 7945.32 7976,75 8008.1 ; 8039.59 8071.01 8102.44 8133,66 8165,26 8196.70 8226,13 8259,55 8290.97 8322.39 8353.82 8385.24 8416.66 ...6. ' ,.. " '"'' , ",' .. ,I. . " It ~. ,:;,..: '''I,...: .:'.:, .,." ,.' :...,.; ,:~,...,.._·,..",~-~.....-t¡\""I'I;""""':':"·':""':"i""I:' ; 'I~~J ,: :::' ,~"~~D1 : , ::: '" ,TVP',,:' ';, ,,,:+~~~S,,:, ""tE/-W,'.. :' V'p;r ": ", ,DI.;~:' : :Bull,d" :': 1 tarn' :": ::':" {f.~,uI/Çu~lIn~nt ",:,:, ': ::', ,',' ,deg , :, ':.. dE1J9, , ": , :' :: : ::1t " ',: :':, , ~ ~.~.._.~_::::,,:.~,~.:... ;,.~::,,,::..:. ,.~,.,.,:,..:..':,.. ,:'..~~.~~~~~~~._~~~~.~~~~~~~~tl~::._ ':, ::; ',:::: :' : < ":' ',::: ,:'; :,,:, :: 5.S5 279.36 620E!.53 -70.35 -2071.16 2071.16 1.07 0.99 -4.20 NS Gyro S.98 280.71 6237.80 ..69,79 -2074.35 2074.35 0.60 0.41 4.23 NS GyrQ 6,06 6.11 5.18 4,66 4.86 4.69 4.55 4,79 4.94 4.79 4.49 4.11 2.93 2.63 2.73 2.79 2.75 2.72 2.76 2.89 2.97 2.83 2.15 1.56 1.54 1.46 0.90 0.64 0.87 0.79 0.69 0.40 0.11 0.17 0.19 0.25 0.28 0.24 0.40 0.S8 0.30 0.32 0.39 0.21 0.16 0.23 0.23 0.31 0.55 0.43 0.37 281.48 282.42 279.93 275.84 273.80 270.94 261.20 259.75 261.40 259.67 254,17 2~5,74 254.14 254,25 262.8a 252.40 254.44 258.00 260.72 261.43 261.83 261.05 250.49 236.43 235.07 235.47 231.71 2M.M 231.69 237.98 238,91 227.94 270,33 343.02 323.93 258,65 302.50 291,05 312.05 322.14 346.56 345.48 329.81 308.95 205.25 221.08 244.11 242.09 262.55 267.60 283.00 6269.04 6300,29 6331,ó5 6S62.87 6394,18 6425.49 6458.61 6488.12 6519.44 6550.75 6582.06 eE!1 :3.40 6644.77 6676.15 6701.54 67:38.92 6770.31 6801.70 6aSS.OS 6864.46 6895.85 6927.23 6958.62 6990.02 7021.44 7052.85 7084.27 7115.68 7147.11 7178.53 7209.94 7241.36 7272.79 7304.21 7335.63 7367.05 7398.48 7429.90 7461.:32 7492.74 7524.17 7555.59 7587' .01 7618.43 7649.86 1681.28 7712.70 7744.12 7775,54 7806.96 7838.38 -69.15 -2077.58 ·68.46 -2080.84 -67.86 -20S3.87 M67.48 -2086.54 ·67.27 ·2089.14 ..67.16 -2091.75 -67.33 -2094.27 ..67.75 -2096.79 -6$.19 -2099.42 -68.62 -2102.05 -69.20 -2104.52 -69.81 ~2106.60 ..70.31 -2108,66 -70.72 -2110.13 -71.14 ·2111,54 -71.59 -211 2.9B -72.02 -2114,43 -72.38 -2115.89 -72.66 ·2117.37 ..72,90 ~2118.90 ..73,13 -2120.46 -73.37 ·2122.06 ..73,68 -2123.38 -74,12 -2124.29 -74.60 ~2124.99 -75.06 -212S.6ì -75.44 -2126.19 ..75,73 -2126.57 -76.01 -2126.95 -76.26 -2127.32 -76.49 -2127.66 ..76.66 -2127.91 -76.73 -2128.02 -76.69 ~2128.06 ~76.eO -2126.11 -76.57 -2128.21 -76.55 -2128.34 -76.4a -2128.46 -76.38 -2128.61 ·76.23 -2128.75 -76.07 -2128.83 -75.90 -2128.88 -75.72 -212a,95 -75.59 -2129.05 -75.60 -2129.11 -75.68 -2129.17 -75,76 -2129.27 -75.83 -2129.40 -75.89 -2129.63 -75.91 -2129.90 -75.89 -2130.11 2077.58 2080.84 2083.87 2086.54 2089.14 2091.75 2094.27 2096.79 2099.42 2102.05 2104.52 2106.80 2108.66 2110.13 2111.54 2112.98 2114.43 2115.89 2117.37 2118.90 2120.48 2122,06 2123.38 2124.29 2124.99 2125.67 2126.19 2126.57 2126.95 2127.32 2127.66 2127.91 2128.02 2128.06 2128.11 2128.21 2128.34 2128.46 2128.61 2128.75 2128.83 2128.88 2128.95 2129.05 2129.11 2129.17 2129.27 2129.40 2129,63 2129.90 2130.11 0.36 0.36 3.06 1.99 0.83 0.93 2.53 0.85 0.65 0.67 1.71 1.27 3.77 0.95 0.38 0.20 0.34 0.55 0.43 0.43 0,25 2.45 0.16 2.99 -2.96 ..7.92 ~1.65 -13.01 0.64 -6.49 -0,54 -9.10 -0.45 -31.00 0,76 -4.61 0.48 5.25 -0,48 -5.51 -0,95 -17.50 -1,21 5,00 -3.75 -5.09 -0.95 0.35 0.32 -4.42 0.19 -1.46 -0.13 6.49 -0.10 11.33 0.13 8.66 0.41 2.26 0.26 0.46 2.60 2.36 0.13 0.26 1.80 0.23 0.16 0.39 0,32 0.96 1.04 0.55 0.20 0.77 0.54 0.21 0.62 0.23 0.25 1.27 ~0.45 -2.48 -2.16 -33.61 -1.86 -44.75 -0.06 -4.33 -0.25 1.27 ø1.78 -11.97 -0.19 a.~i' 0.10 ø8,43 -0.25 20.02 øQ,32 2.96 -0.92 -34.91 -0.92 134.87 0.19 231.35 0,06 -60.76 0.19 -207.77 0.10 1:;9.52 -0.13 -36.44 0.51 66.84 -0.06 32.11 -0.25 77.70 0.06 -3.44 0.22 -49.87 -0.57 -66.39 -0.16 -329.94 0.52 0.07 0.38 0.66 0.93 0.28 0.29 0.26 0.89 0.41 0.39 0.22 0.00 0.25 0.76 -0,38 -0.19 50.38 IS.30 -6.43 65.10 16,07 49.01 NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gym NS Gyro NS Gyro N$ Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro Jun-20-02 08:46am From-MARATHON ' ') +9155646489 Survey Report ) T-345 P.08/09 F-384 " I :. '. I ., I','·'''''' :':1" :',' .. : . .. "'1"1:"1:.;:, ',' ":..,' :,:"""""1" ,',": " '. . ... ':: :.: ".DateL 4/3/2002 "':'.:. 1)wtl:·.· ~ 3:34:.10. .: :... ,'.. .... '. . ,:~~ge;: ,: ,:. "6' I .: ...: , . .' . : : .:: : ..;Co.:o,.~ìn¡~(NE):Rerer~neÐ':· , : :W~.II;·'F.äIlS'Creel(#1, Tr:u~'t"ort~·. ::' '. ,;.' ,:'.'.: ':. , . . : .: ,". " .: : )'I!r,i~al (TVD)'R,r~r~me'e':> ::. :curr.ent:Drllll~ø.266.a::: '::.:.... ' ,: :'.::'::: :::::: .: , '.,,, ",:':' : : Seçtjo",(VSn{~fÐrenee: ''',::: ;Wélnç¡:,QON·.O;OOE;270~OOAiir !.... ".':':' ,:':.: , ' :: ,.". :~,:,,::.": ,::,': :. ':. : SlIfVèY Cal.~~lätio~.~etbod: ,:. ::. ~¡~!",ulTi. Curyawre:: . '. . :. ,~",: .:~.~b:·: ',Sybase: ,,: :. ~~t~~p~~~~:: :,M,~~~~~.~~q:ii',~o:~~~~Y,: ,:: .:;: ~:.:: : ." , :F.leld;, ::. .: ,Falls:CreElk..::·',:·.:. "",. . " '. . .: ·:~'te:: : .:',' ·:Fail~·Cr.~ElK:locatl<?n::·::::·;: ':.::: '. :.' '.:' WèU:. ': .:.' : F¡III$ Gr.eek.:#1": ' ':.. ; , ,:.. .:" '. .:" ; .~el1p,ä1h:: :.: $¡~~!.~c~:. .:, ,: '.'. ,.': ': : : :'.':" .:.: .:,' "..:: :.: ,~"'ïD;:~, :,.;~ ~.: '.... ;:;;;;,:,. ....: .~~. 8448.08 0.58 306.73 7869.80 8479.51 0.67 ~07'.18 7901.23 8510.9:3 0.91 306.09 79~2.65 8542.35 1.32 g02.10 7964.08 8573.77 1.32 301.ß6 7995.47 8605.20 1.50 297.48 6026.89 8636,62 1.62 303.18 8058.30 8668.04 1.77 300.56 8089.71 8899.46 1.73 301.79 8121.11 8730.69 2.00 307.02 8152.53 8762.31 2,13 ~12.27 8183.93 8793,73 2.19 311.53 8215.32 aS25.15 2.30 314.78 8246.72 8856.58 2.29 314.65 6278.12 8888.00 2.43 ~17.47 8309.52 8900.00 2.43 317.47 8321.51 . :+NJ-S :.' ; ,. ff'" ' -75.76 -75.57 ~ 75.31 -14.97 ':. ::,:: t~~~':?:"':::,:,v::!:.:"" -2130.34 2130.34 ~2130.61 2130.61 -2130.96 2130.96 -2131.47 2131.47 -74.59 -2132.08 -74.21 -2132.78 -73.78 -213g.49 -73.2a -2134.28 -72.79 -2135.10 -72.21 -2135.94 ·71.49 -2136.61 "70.70 -2137.70 -69.85 -2138.59 -68.97 -,2139.49 2132.08 2132.76 2133.49 2134.28 .2135.10 2135.94 2136.81 2137.70 2138.59 2139.49 -68.04 -2140.38 2140.38 -67.66 -2140.73 2140.73 , : ,n!:,s "-·':·."·,':,'B~.'ild ,: :' : : ':T~m:' ::. . :. ' .: ;1·.'·;;'~.:VCø. .·anm. ent:' ' .-"..."...,.,.. "" r, I.;:. t :.1::, I. : '~~~1~~9~,:de9J100ft~d$9J~:09,~:. ';..:.': ,,": :."', :.':: "::.:'..,..~~ 0.90 0.67 75.53 NS Gyro 0.29 0.29 1 ,43 NS Gyro 0.77 0.76 -3.47 NS Gyro 1.33 1.30 -12.70 NS Gyro 0.03 0.66 0.82 0.54 0.17 1.01 0.73 0.21 0,54 Q.04 0.58 0.00 0.00 0.57 0.38 0.48 -0.13 0.86 0.41 0.19 0.36 -0.03 0.45 0.00 -1.40 -13.30 18.14 -8.34 3.91 16.64 16.71 -2.36 10.34 -0.41 8.96 0,00 NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro N$ Gyro NS Gyro .....-..- Tatgets: :' ,,::,:::'~''::''':'.',':.':~'-.:. , ;,:;; '.: .: ,:': ,-:::'" ::',"':.' ':' :',:: :' ., :,' '''~,.'.:. . . '. .' "Map: ';;"'" ':" 1Vl3P :.':. ':,"; <:".;":,,.. .L~tit.;.ï~,,:¡.;..~,'·: '.~; l.~~:¡;it;;d~ ;.~~.' ! ~~~~. > :,':, :-::,':, : :¡ 'Dl!ti~rip(ion ;.'.' : r,YD:.:' '. :.·~N/-S ::.' ; . : ·.1;~/..W'::' :Nort.blllg ': ~.~tin& ...,': . :Dt~ :1\-111\: : $~(:: : ::~ .:. ,,,Dç~ 1\1iö ':.~'~~":::::. , : ,':. '.: ':'. .,'.':.: ',;.';,: I ':. ::';'.'::'.':. :,'. : ,,: : 'ft .:. .'. .: ft ': .:,.~ :, : ft:: :,:' : '. :. ,"ft . '. '. : ~.:.".'.~:, ft.. ::.:: ,,':, .:" ::. "i. : ': . ,i '.', ":" .> . ",; ': .:': : ,; : ': :< <!.' :~.i Target 1 5006.00 0,00 -1750.00 2269488,09 238190.51 60 12 15.856 N 151 26 20.948 W ------ . ...- Alaska ~ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 June 14,2002 Mr. Steve Davies Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 VIA CERTIFIED MAIL RE: Marathon Falls Creek #lrd AOGCC Forms 10-407 and Form 10-421 CONFIDENTIAL Dear Steve: Enclosed are the Well Completion or Recompletion Report and Log (Form 10-407) and Gas Well Open Flow Potential Test Report for the above referenced well. Thank you, 1ip-lO~ Kaynell Zeman Technical Assistant Enclosures Receipt: 7001 251000030681 7887 RECEIVED JUN 1 8 2002 Alaska Oil & G"s f"'.~ - Ana \.IUns. GOil1m¡SSJOr. chorage Environmentally aware for the long run. 1 a. TEST: INITIAL ANNUAL SPECIAL ) ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT x 1 b. TYPE TEST MULTIPOINT ~ OTHER 2. Name of Operator Marathon Oil Company 3. Address STABLlLlZED D NON STABILIZED CONSTANT TIME ISOCHRONAL 7. Permit No. 201-155 8. API Number 50- 133-1 0005-01 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 4. Location of Well At surface 1898'FSL,2885'FEL Section 6, T1N, R12W, S.M. 5. Elevation in feet 282' 12. Completion Date 4/02 16. Csg. Size 4-1/2" 17. Tbg. Size 18. Packer set at ft. 23. 24. No. 1. 2. 3. 4. 5. Prover Line Size (in.) 3.826 3.826 Basic Coefficient (24-Hour) No. Fb or Fp 1. 32.9 2. 33.6 3. 4. 5. No. Pr 1. 0.9238 2. 0.8798 3. 0.0000 4. 0.0000 5. Form 10·421 Rev. 7-1·80 kz\AOGCCGAS.XLS RECEIVED JUN 1 8 2002 (KB, OF etc.) AJask8EÜÌi~~ ~OOl91JBØfNo. AD L -0059<Änchoraoe 13. Total Depth 14. Plugback T.D. 8,900 8790 (Cement) Weight per foot, lb. I.D. in inches 12.6 3.958 Weight per foot, lb. I.D. in inches 19. GOR cf/bbl. 9. Unit or Lease Name Falls Creek Unit 10. Well Number Falls Creek #1 rd 11. Field and Pool Falls CreekfTyonek 15. Type Completion (Describe) 4-1/2" Monobore Set at ft. Perforations: From 8,900 8714 Set at ft. To 8750 20. API Liquid Hydrocarbons Reservoir Temp. of. 148 Ga. x Flow Data Choke Orifice Size (in.) 2 2 Temp. of. 44 34 22. Producing thru: Tbg·D csg.[K] Length of flow channel (L) Vertical Depth (H) 8796 8136 Pressure psig 630 600 Diff. hw 52 68 x X X 21. Specific Gravity Flowing fluid (G) 0.57 Mean Annual Temp. of. 40 Barometric Pressure (Pa), psia 14.73 % CO, % N2 o 0 Tubing Data Prover Taps Meter run X %H2S o Casing Data Pressure psig 2380 2300 Temp. of. 67 70 Pressure psig Temp. of. Duration of Flow Hr. 14.000 2.000 ,/ hwPm Pressure Flow Temp. Factor Gravity Factor Super Compo Factor Rate of Flow Pm Ft Fg Fpv 0, Mcfd 181.0 644.7 1.0157 1.325 1.0458 5,950 202.0 614.7 1.0260 1.325 1.0491 6,790 Fig 3-30 GPSA Temperature for Separator Gas for Flowing Fluid T Tr Z Gg G 504 1.469 0.9144 0.57 494 1.440 0.9086 460 1.341 0.9297 Critical Pressure 682 460 1.341 0.9326 Critical Temperature 343 CONTINUED ON REVERSE SIDE Submit in duplicate ) ) Pc 2,910 Pc2 8,468,100 Pf 3,692 Pf2 13,630,864 No. Pt Pt2 Pc2 - Pt2 Pw Pw2 Pc2 - Pw2 Ps PS2 Pf2 - PS2 1. 2,380 5,664,400 2,803,700 1,895 3,590,646 10,040,218 2. 2,300 5,290,000 3,178,100 2,236 4,997,907 8,632,957 3. 0 0 8,468,100 2,488 6,188,651 7,442,213 4. 0 0 8,468,100 2,737 7,488,432 6,142,432 5. 0 0 25. AOF (Mcfd) 14,461 n 0.844904 Remarks: 2-point test conducted on 4/09-10/2002 using downhole and surface electronic gauge recorders. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~t. vJJLJL Signed 5/30/2002 Title Adv. Production Engineer Date AOF DEFINITIONS OF SYMBOLS Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T 2 Form 10-421 Rev. 7-1-80 kz\AOGCCGAS.XLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ ~ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ 1/2 dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless RECEIVED JUN .} 8 2002 Alaska Oil &. Gas ;_:C(Jf·¡ ~WiH;I;-j."';' I 4nchor~Qf Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma CONTINUED ON REVERSE SIDE Submit in duplicate FC-1 rd Test #1: ) ') 8714' - 50' MD (04/10/02) 2-Point Test Downhole Data (Measured) W AM file == FGU1RD_1 0 Pr Pwf PTHP D.H. DD Actual Calc. Regression % Ditt. in Q (Mcfd) (psia) (psia) (psia) (%) (P r2.p wf 2) C (0) (%) 5,950 3,692 2,919.4 2,395 20.9% 5,107,968 0.0441 6,118 2.8% 6,790 3,692 2,824.9 2,315 23.5% 5,650,804 0.0466 6,609 2.7% 3,692 14.7 14.7 99.6% 13,630,648 0.0000 12,959 #DIV/O! 3,692 14.7 14.7 99.6% 13,630,648 0.0000 12,959 #DIV/O! Ave. Coett. C 0.04532 12,959 n= 0.764777 Mcf/psi2 Regression 'c' 0.04532 AOF= 12,959 Mcfpd Surface Data (Measured) 0 Ps Pwf PTHP Surf. DD Actual Calc. Regression % Ditt. in Q (Mcfd) (psia) (psia) (psia) (%) (P r2.p wf 2) C (0) (%) 5,950 2,988 2,395 19.8% 3,192,119 0.0190 6,065 1.9% 6,790 2,988 2,315 22.5% 3,568,919 0.0198 6,664 1.9% 2,988 14.7 99.5% 8,927,928 0.0000 14,461 #DIV/O! 2,988 14.7 99.5% 8,927,928 0.0000 14,461 #DIV/O! Ave. Coett. C 0.01939 14,461 n= 0.844904 Mcf/psi2 Regression 'c' 0.01939 AOF= 14,461 Mcfpd 100,000,000 --- - - - - - - - . - 10,000,000 - -.=_______, - -. - -.~ . -~ _-1 I ~-.::::¡øL -~- - . . - - - - - .-. C\I .! U) Co '-' . ...---.1 _ "."-iL--" C\I}: 1,000,000- a.. ----,--- --- I C\I a:- 100,000 .._-_.,----~- ----.----.------ -----------,. 10,000 1000 10000 Q, (Mcfpd) 100000 . Downhole Surface Regression Downhole Regression Downhole AOF Line . Surface Data - ·Surface AOF Line Static Pressure Date Surface Downhole (psia) (psia) 08/02/01 2,531 3064.6 O:\ninilchik\GO 1 testing\FC-1 rd 2-Pt TesC0402.xls Analysis 8/10/01 +. , 2 - . 3 . 4 . I I I I 11 I 11 I I I I~'f I I. 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J VL.:._ c- L ' /,. c- J r-+ - ....L _L f IT",.- _ _ ,.' ~ ! ('-' c=.> C/- 300'-, ~- I~ - -1' ;-E.~ I '-"- _.... ''¿ t L-- ::Jt. + ,:- -, "",' ;... + -' '- ./ "'- . .... ., 4 r. '-~ ~ Q:; " - :02,--5 J___-~ 1 + ( .'" J !B =J'-, ~ '7 t -z. 0-,. ~ '~ c:.' i ~ç ::' -/? J /,7' ?pcer son} - ~ e I I I I --1 ! --1 I ---t ¡- . ~ I I : fB ¡- II ) 1/ /1 // 1/ I! ¡ -' I -- ----, ,..-- Ii !/I í/ ,/ ~" h,l 7 t·l.T'-- ~' /¡ ~ fj t::- ) í , i::t! tI I ( '" ": Cr)í/ /1 ... - -4 I 3 // &~ 12 ,,/ f~-·e ! i I . ,r , j , , i -. / .- ,.. .- t -+---.- .r' ¡I '.,,., ." ~_-v'-_.n- I f ,'/ ! / ' 'I " '/ . ,_ 1- -;; :'6~ -f.;r _ _ _ .,. Ç$ '7? t /~a - -,~ _ (() ~ ' SO-RD. I <:>. . t - ..+ F /1 011' . . .300~J ~ )/. ~ ~ r ,/.{. ~.. I#. P~dersOI1) f - ", ~)' - /" I 14~ ,: t .. .. ¡i .' ~i ./ /' / 0;) / ; , . ~."'" / ~ /--~ 'i,.I -22is"')I 13 .. .- / ;_. aT f::~""IU'''''' Sd/Jd' r I I i l IA SO -RO ADL 00590 '/?OXIAlATE ìURF4CE c0REEK C1: --.-.-.. I · I · I - I · I . I ) Survey Report \ ._.-..-~-..._~._-"_..._.-----,-_..~-~_.,_.-._---.-._,-.---"-'~_'~_'_'~_"'_---"-'-'---'.~..._-,~.__._,..._.~.'.-------.--- aoJ--J55 _._-_.~._---_..__...._~- Company: Field: Site: Well: Wellpath: Field: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek #1, True North Falls Creek location Vertical (TVD) Reference: Current Drilling 266.0 Falls Creek#1 r.\\'T\~\.. Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Si::~~~:e~k--------_._-------tQ\\f\ Ðt.\'_~____.~~~~~~_~alc~~~tion Met.~od: -e____rvtinimum ~~rva.ture ___.._._.~~___Sybase USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level --.---.-..,.-.-.-.- Site: Falls Creek location -_.~-------_...__. _.·___~_w___.__. Sec. 6, T1N, R12W, Kenai Borough Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft ._----,-,-- Well: Falls Creek #1 --..-.-..-..-.,--..--.---- --.-.---..,..---.------ Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre Wmm_95 ,---..----.----.----,---.-,--.----.---,.-. 2269450.20 ft 239940.10 ft __._._u______.,'__________".___________~_____.._.___.__._,______ -.------.-----.-- Latitude: 60 12 15.857 N Longitude: 151 25 46.322 W North Reference: True Grid Convergence: -1.24 deg ----....--.-----.-"..- -~-,,_....._--_..__.._._-_._-------~..~--_.- ---_._--_...,-_."~_._-_....__......_----~--_....,--_._.._~---.----- Well Position: +N/-S +E/-W Position Uncertainty: 0.00 ft Northing: 2269450.20 ft 0.00 ft Easting : 239940.10 ft 0.00 ft ~ -...-._~---.'- Slot Name: Latitude: Longitude: 60 12 15.857 N 151 25 46.322 W ______h"__..,~_.~...___.______.___~____.__.~_..._____~_._____....__..__..._'"___ -~-,---~-_._-_..,--_..__.,--- _..._..--,-----_._--_.._-,-_._----_.~-----_."-_.._..,-- Drilled From: Original Wellbore Tie-on Depth: 3150.00 ft 266.00 ft Above System Datum: Mean Sea Level Declination: 21.05 deg Mag Dip Angle: 73.23 deg +N/-S +E/-W Direction ft ft deg -_._._---_._,~._-----~._,._..-.._.__.__...__._-,--.._---..~--_._~---.__.------- ..._~_._------_.__.__."..__._-_._._----_._,---_._._~-----.--.-- 0.00 0.00 270.00 Wellpath: Sidetrack Sidetrack to regain productive interval Current Datum: Current Drilling Height Magnetic Data: 8/9/2001 Field Strength: 55079 nT Vertical Section: Depth From (TVD) ft 0.00 ~.- .-,.----.--.--.-.--..--....- ._._.._._._.~_.._-----_._-- -----.----.,---.----... ..____.____.._.__·__.,_.._..··_m_._ ~____..__..__.._ ._____~_.._._..__.____...__,._..__._.__._._._.___.~._____." __M_"__'_ ._.____.__._M._'._..__..._'_M_._._.__.______,___.____.._.__________. 8/17/2001 Survey: Gyro Survey of Sidetrack Gyro Survey after TD Company: Gyrodata Tool: NS Gyro, Start Date: Engineer: Tied-to: Tom Stoddard From Surface - ----_.__...__._-"._---_..__._~_._--------------_.._-..--,....--..-.---...-.-.- Survey: Gyro Survey of Sidetrack --_._---_._...~-,..._~.._._----_. -_....~---,~-.._._-_...~...__....--_..~._-~..- -_._.~._,-~~.._,.._._.....-."....."-,...".,..-...,_._-~.---".._--_..~,..__._.. -...--,,----.--.-.----- --------.- MD Inel Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment __~______~~~_______~_~~_._._.___._~_..__..___!!__..._________ft_..__.______...~___..._._~~5!L~?_~_.~eg/~~!!~deg/1 O~~.__._____ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 NS Gyro 1095.22 0.10 287.26 1095.22 0.28 -0.91 0.91 0.01 0.01 0.00 NS Gyro 1126.64 0.33 298.02 1126.64 0.33 -1.02 1.02 0.74 0.73 34.25 NS Gyro 1158.07 0.35 303.82 1158.07 0.43 -1.18 1.18 0.13 0.06 18.45 NS Gyro 1189.49 0.36 305.62 1189.49 0.54 -1.34 1.34 0.05 0.03 5.73 NS Gyro 1220.91 1252.33 1283.76 1315.18 1346.60 1378.02 1409.45 1440.87 1472.29 1503.71 1535.14 1566.56 1597.98 1629.40 1660.83 1692.25 1723.67 1755.09 !_n~!.~·_~__ 0.38 0.40 0.43 0.48 0.62 0.85 1.21 1.76 2.43 3.36 4.45 5.63 6.56 7.38 8.07 9.07 10.04 11.13 12.56 299.20 290.28 279.07 268.18 256.93 239.21 237,70 232.21 231.07 230.86 232.69 232.68 231 .42 232.50 233.04 233.11 234.22 235.77 238.10 ,-----,.--.--.-- 1220.91 1252.33 1283.76 1315.17 1346.59 1378.01 1409.44 1440.85 1472.24 1503.62 1534.98 1566.28 1597.52 1628.71 1659.85 1690.92 1721.90 1752.79 1783.55 _.~--_._----_...- 0.61 0.31 -0.16 -0.87 -1.87 -3.20 -4.87 -6.92 -9.27 -11 .83 -14.64 -17.73 -21.03 -24.55 0.65 0.74 0.79 0.81 0.77 -1.51 -1.70 -1.92 -2.17 -2.47 -2.83 -3.31 -3.98 -4.88 -6.11 -7.79 -9.99 -12.62 -15.62 -18.98 -22.73 -26.93 -31.66 -37.07 1.51 1.70 1.92 2.17 2.47 2.83 3.31 3.98 4.88 6.11 7.79 9.99 12.62 15.62 18.98 22.73 26.93 31.66 37.07 0.15 0.20 0.27 0.32 0,56 0.06 -20.43 0.06 -28.39 0.10 -35.67 0.16 -34.66 0.45 -35.81 1.02 1.15 1.81 2.14 2.96 0.73 -56.40 1.15 -4.80 1.75 -17.47 2.13 -3.63 2.96 -0.67 3.47 5.82 3.76 -0.03 2.96 -4.01 2.61 3.44 2.20 1.72 3.49 3.76 2.99 2.64 2.21 3.18 3.18 3.14 3.09 3.59 3.47 4.80 4.55 0.22 3.53 4.93 7.41 ___.______. .__ - _._u __"'___._"_.__ NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro ) ) Survey Report ______~_.".._"...__.~._..___.m._~_.~.__~.._._.___~.____~_..~_._'"N_.._·_..n_,.·._~~___.____..___.._._.____'"__.__~___. -'..._.'---"-~'--' Company: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: 2 Field: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek #1, True North Site: Falls Creek location Vertical (TVD) Reference: Current Drilling 266.0 Well: Falls Creek #1 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Sidetrack Survey Calculation Method: Minimum Curvature Db:Sybase .._-~~_._--,_._-~-~,.~_..._-------_._-_._-------_----..-...._. Survey: Gyro Survey of Sidetrack ----_.__._._.._-_._.._-----_..._-------_._--~,_._.....-.-.-.-- ·....__....__·_...._,.__..c_._...._.__.._...___...____.._._.___,,___._.__.__.___~__.____.. MD Inel Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft ~--'--'--"-"--'--~"---"-~~' h__..___.·.__.,,___.'.,_.,_,._~.·~._....________._,__,_.'.__,_..~______._ .--- ----------~- 1817.94 13.81 241.52 1814.14 -28.14 -43.27 43.27 4.69 3.98 10.88 NS Gyro 1849.36 15,07 241.53 1844.57 -31.87 -50.15 50.15 4.01 4.01 0.03 NS Gyro 1880.78 16.14 241.21 1874.83 -35.93 -57.57 57.57 3.42 3.41 -1.02 NS Gyro 1912.21 16,69 241.46 1904.98 -40.19 -65.37 65.37 1.76 1.75 0.80 NS Gyro 1943.63 16.90 241.75 1935.06 -44.50 -73.35 73.35 0.72 0.67 0.92 NS Gyro 1975.05 16.95 241.62 1965.12 -48.84 -81.40 81.40 0.20 0.16 -0.41 NS Gyro 2006.47 16.82 242.11 1995.18 -53.14 -89.45 89.45 0.61 -0.41 1.56 NS Gyro 2037.90 16.67 241.34 2025.28 -57.43 -97.43 97.43 0.85 -0.48 -2.45 NS Gyro 2069.32 16.70 241 .46 2055.38 -61.75 -105.35 105.35 0.15 0.10 0.38 NS Gyro 2100.74 16.81 241 .40 2085.46 -66.08 -113.30 113.30 0.35 0.35 -0.19 NS Gyro 2132.16 16.57 242.01 2115.56 -70.36 -121.25 121.25 0.95 -0.76 1.94 NS Gyro 2163.59 16.35 241.90 2145.70 -74.55 -129.11 129.11 0.71 -0.70 -0.35 NS Gyro 2195.01 16.36 242.17 2175.85 -78.70 -136.92 136.92 0.24 0.03 0.86 NS Gyro 2226.43 16.38 242.28 2206.00 -82.82 -144.76 144.76 0.12 0.06 0.35 NS Gyro 2257.85 16.38 242.62 2236.14 -86.92 -152.61 152.61 0.31 0.00 1.08 NS Gyro 2289.28 16.42 242.82 2266.29 -90.99 -160.50 160.50 0.22 0.13 0.64 NS Gyro 2320.70 16.33 242.94 2296.44 -95.03 -168.38 168.38 0.31 -0.29 0.38 NS Gyro 2352.12 16.12 242.47 2326.61 -99.05 -176.18 176.18 0.79 -0.67 -1.50 NS Gyro 2383.54 15.91 242.36 2356.81 -103.07 -183.87 183.87 0.68 -0.67 -0.35 NS Gyro 2414.97 15.72 243.15 2387.05 -1Ò6.99 -191.48 191.48 0.91 -0.60 2.51 NS Gyro 2446.39 15.94 243.18 2417.28 -110.86 -199.13 199.13 0.70 0.70 0.10 NS Gyro 2477.81 16.41 242.73 2447.45 -114.84 -206.93 206.93 1.55 1.50 -1.43 NS Gyro 2509.23 16.81 242.93 2477.56 -118.94 -214.92 214.92 1.29 1.27 0.64 NS Gyro 2540.66 17.21 242.50 2507.62 -123.15 -223.09 223.09 1.33 1.27 -1.37 NS Gyro 2572.08 17.52 241.92 2537.60 -127.53 -231.38 231.38 1.13 0.99 -1.85 NS Gyro 2603.50 17.71 240,95 2567.55 -132.07 -239.73 239.73 1.11 0.60 -3.09 NS Gyro 2634.92 17.99 241.14 2597.46 -136.74 -248.16 248.16 0.91 0.89 0.60 NS Gyro 2666.35 18.39 241.09 2627.32 -141.48 -256.75 256.75 1.27 1.27 -0.16 NS Gyro 2697.77 18.20 242,52 2657.15 -146.14 -265.44 265.44 1.55 -0.60 4.55 NS Gyro 2729.19 1 7.40 245.44 2687.07 -150.35 -274.07 274.07 3.81 -2.55 9.29 NS Gyro 2760.61 16.74 250.07 2717.10 -153.85 -282.60 282.60 4.81 -2.10 14.74 NS Gyro 2792.04 16.72 255.71 2747.20 -156.51 -291.23 291.23 5.16 -0.06 17.94 NS Gyro 2823.46 17.45 259.94 2777.24 -158.45 -300.25 300.25 4.59 2.32 13.46 NS Gyro 2854.88 18.47 262.85 2807.13 -159.89 -309.83 309,83 4.32 3.25 9.26 NS Gyro 2886.30 18.58 263.39 2836.92 -161.08 -319.74 319,74 0.65 0.35 1.72 NS Gyro 2917.73 18.50 263.13 2866.72 -162.26 -329.67 329.67 0.37 -0.25 -0.83 NS Gyro 2949.15 18.30 263.25 2896.53 -163.43 -339.51 339,51 0.65 -0.64 0.38 NS Gyro 2980.57 17.67 263.37 2926.42 -164.56 -349.15 349,15 2.01 -2.01 0.38 NS Gyro 3011.99 17.66 263.43 2956.36 -165.66 -358.62 358.62 0.07 -0.03 0.19 NS Gyro 3043.42 1 7.48 264.02 2986.32 -166.70 -368.05 368,05 0.81 -0.57 1.88 NS Gyro 3074.84 18.90 265.47 3016.17 -167.59 -377.82 377.82 4.74 4.52 4.61 NS Gyro 3106,26 20.50 266.31 3045.75 -168.35 -388.38 388,38 5.17 5.09 2.67 NS Gyro 3137.68 23.05 266.19 3074.92 -169.11 -400.01 400,01 8.12 8.12 -0.38 NS Gyro 3169.11 23.98 266.57 3103.74 -169.90 -412.53 412,53 3.00 2.96 1.21 NS Gyro 3200.53 25.45 266.90 3132.28 -170.65 -425.64 425.64 4,70 4.68 1.05 NS Gyro 3231.95 27.28 266.83 3160.44 -171.41 -439.57 439.57 5.83 5.82 -0.22 NS Gyro 3263.37 28.91 267.28 3188.15 -172.17 -454.35 454.35 5.23 5.19 1.43 NS Gyro 3294.80 30.40 268.23 3215.47 -172.77 -469.89 469.89 4.97 4.74 3.02 NS Gyro 3326.22 31.68 269.01 3242.39 -173.16 -486.08 486.08 4.27 4.07 2.48 NS Gyro 3357.64 32.59 268.63 3268.99 -173.51 -502.79 502.79 2.97 2.90 -1.21 NS Gyro 3389.06 33.45 271.41 3295.34 -173.50 -519.91 519.91 5.54 2.74 8.85 NS Gyro 3420.49 34.05 272.43 3321.47 -172.91 -537.36 537.36 2.63 1.91 3.25 NS Gyro 3451.91 35.27 273.21 3347,32 -172.03 -555.21 555.21 4.13 3.88 2.48 NS Gyro -'. ----- ----,----" - --'--.-'- --- --...-.------.-------..-.-,--'",-,---.. ~-'-' -,,--~. ------,-~,,- --. -.-."-.,,----.,-.--,,-----, ---,-----~--_.~- ) ) " Survey Report .__..._---._--_._--_.---._,--_._~------_.~._-~-"..._--_.~--,-_.._.._-.._----. -----_.._--~----..-.._------ Company: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: 3 Field: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek #1, True North Site: Falls Creek location Vertical (TVD):Reference: Current Drilling 266.0 Well: Falls Creek #1 Section (VS) Reference: Well (0.00N,O.00E,270.00Azi) Wellpath: Sidetrack Survey Calculation Method: Minimum Curvature Db: Sybase ---_._.__._._-_.._----------_...~_.._._-_.,_.._.-.._...-. ~_____.______u".. Survey: Gyro Survey of Sidetrack ---_..._-_._..~.__..__.._. .. -.--..-.-.--.---.--,--...-.,,-.--..,-.'--..---,-".------..._....._-_...-._---~_.__..'--_._.....,,_....-.,.._------,.-....-.....-.,-....----...--.-.--.--.---...-.-----."'----..-.---,,-..-.---.... MD IncI Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft .._..__,'__-..........__._~_~_~w___,,____."..,__~.. ..'-<._--_.._._~..~._.,_.~-~._.._.- -~._----_._--- ___'W~_~ 3483.33 36.80 274.09 3372.72 -170.85 -573.65 573.655.14 4.87 2.80 NS Gyro 3514.75 38.25 274.59 3397.64 -169.40 -592.74 592.74 4.72 4.61 1.59 NS Gyro 3546.18 39.84 274.39 3422.05 -167.85 -612.47 612.47 5.07 5.06 -0.64 NS Gyro 3577.60 41.38 274.90 3445.90 -166.19 -632.86 632.86 5.01 4.90 1.62 NS Gyro 3609,02 42.70 275.78 3469.24 -164.23 -653.80 653.80 4.60 4.20 2.80 NS Gyro 3640.44 42.96 276.06 3492.28 -162.03 -675.05 675.05 1.03 0.83 0.89 NS Gyro 3671.87 43.12 276.46 3515.25 -159.69 -696.37 696.37 1.01 0.51 1.27 NS Gyro 3703.29 43.48 275.88 3538.12 -157.38 -717.80 717.80 1.71 1.15 -1.85 NS Gyro 3734.71 43.72 275.89 3560.87 -155.15 -739.35 739.35 0.76 0.76 0.03 NS Gyro 3766.13 44.14 276.17 3583.50 -152.86 -761,03 761.03 1.47 1.34 0.89 NS Gyro 3797.56 44.66 276.66 3605.96 -150.41 -782.88 782.88 1.98 1.65 1.56 NS Gyro 3828.98 44.90 276.48 3628.26 -147.87 -804.87 804.87 0.86 0.76 -0,57 NS Gyro 3860.40 45.18 277 .16 3650.46 -145.23 -826.94 826.94 1.77 0.89 2,16 NS Gyro 3891.82 45.43 276.41 3672.56 -142.60 -849.12 849.12 1.87 0.80 -2.39 NS Gyro 3923.25 45.51 276.57 3694.60 -140.06 -871.38 871.38 0.44 0.25 0.51 NS Gyro 3954.67 44.38 277.82 3716.84 -137.29 -893.40 893.40 4.56 -3.60 3.98 NS Gyro 3986.09 43.79 277.38 3739.41 -134.39 -915.07 915.07 2.12 -1.88 -1 .40 NS Gyro 4017.51 44.16 277.92 3762.02 -131.49 -936.69 936.69 1.68 1.18 1.72 NS Gyro 4048.94 44.43 277.78 3784.51 -128.49 -958.44 958.44 0.91 0.86 -0.45 NS Gyro 4080.36 43.10 277.85 3807.21 -125.54 -979.97 979.97 4.24 -4.23 0,22 NS Gyro 4111.78 41.71 278.89 3830.41 -122.46 -1000.93 1000.93 4.96 -4.42 3,31 NS Gyro 4143.20 42.12 278.20 3853.79 -119.34 -1021.69 1021.69 1.96 1.30 -2.20 NS Gyro 4174.63 42.31 277.08 3877.06 -116.53 -1042.62 1042.62 2.47 0.60 -3.56 NS Gyro 4206.05 42.57 277.80 3900.25 -113.78 -1063.64 1063.64 1.75 0.83 2.29 NS Gyro 4237.47 42.81 277 .18 3923.35 -111.01 -1084.76 1084.76 1.54 0.76 -1.97 NS Gyro 4268.89 42.81 277.52 3946.40 -108.28 -1105.94 1105.94 0.74 0.00 1.08 NS Gyro 4300.32 43.13 277 .83 3969.39 -105.41 -1127.17 1127.17 1.22 1.02 0.99 NS Gyro 4331.74 43.06 278.09 3992.34 -102.44 -1148.43 1148.43 0.61 -0.22 0.83 NS Gyro 4363.16 43.20 278.55 4015.27 -99.33 -1169.68 1169.68 1.10 0.45 1.46 NS Gyro 4394.58 43.00 276.64 4038.21 -96.50 -1190.96 1190.96 4.20 -0.64 -6.08 NS Gyro 4426.01 42.61 278.32 4061.27 -93.72 -1212.14 1212.14 3.84 -1.24 5.35 NS Gyro 4457.43 41.59 276.55 4084.58 -90.99 -1233.02 1233.02 4.98 -3.25 -5.63 NS Gyro 4488.85 40.58 275.94 4108.27 -88.74 -1253.55 1253.55 3.46 -3.21 -1.94 NS Gyro 4520.27 39.22 275.48 4132.37 -86.73 -1273.60 1273.60 4.43 -4.33 -1 .46 NS Gyro 4551.70 38.91 275.85 4156.77 -84.78 -1293.31 1293.31 1.23 -0.99 1.18 NS Gyro 4583,12 38.95 274.96 4181 .22 -82.92 -1312.97 1312.97 1.78 0.13 -2.83 NS Gyro 4614.54 39.10 274.97 4205.63 -81.21 -1332,67 1332.67 0.48 0.48 0.03 NS Gyro 4645.96 37.86 274.30 4230.22 -79.63 -1352.16 1352.16 4.16 -3.95 -2.13 NS Gyro 4677.39 37.76 273.00 4255.05 -78.40 -1371,39 1371.39 2.56 -0.32 -4.14 NS Gyro 4708.81 36.66 273.24 4280.08 -77.37 -1390.36 1390.36 3.53 -3.50 0.76 NS Gyro 4740.23 36.29 273.06 4305.34 -76.34 -1409.01 1409.01 1.23 -1.18 -0.57 NS Gyro 4771.65 35.46 271.62 4330.80 -75.59 -1427.41 1427.41 3.77 -2.64 -4.58 NS Gyro 4803.08 35.48 271.26 4356.40 -75.13 -1445.64 1445.64 0.67 0.06 -1.15 NS Gyro 4834.50 35.76 271.56 4381.94 -74.68 -1463.93 1463.93 1.05 0.89 0.95 NS Gyro 4865.92 35.61 270.06 4407.46 -74.42 -1482.26 1482.26 2.83 -0.48 -4.77 NS Gyro 4897.34 34.40 271.44 4433.20 -74.18 -1500.28 1500.28 4.60 -3.85 4.39 NS Gyro 4928.77 33.62 271.99 4459.25 -73.66 -1517.85 1517.85 2.67 -2.48 1.75 NS Gyro 4960.19 32.71 272.48 4485.55 -72.99 -1535.03 1535.03 3.02 -2.90 1.56 NS Gyro 4991.61 32.30 273.53 4512.05 -72.11 -1551.89 1551.89 2.22 -1.30 3.34 NS Gyro 5023.03 32.36 273.23 4538.60 -71.12 -1568.66 1568.66 0.55 0.19 -0.95 NS Gyro 5054.46 32.03 273.38 4565.20 -70.15 -1585.38 1585.38 1.08 -1.05 0.48 NS Gyro 5085.88 31.30 272.69 4591.94 -69.28 -1601.85 1601.85 2.59 -2.32 -2.20 NS Gyro 5117.30 31.03 272.46 4618.82 -68.54 -1618.09 1618.09 0.94 -0.86 -0.73 NS Gyro -----.--.--.---.-- -._-------- ) ) Survey Report '~'--'-'"------'~-'-'--"--"~'--"-----'-'-"-'''''-'-------~.~.-.,.__._.._-~-,.,,~_...--_. ----_.-,~_.__..,,-_._--_.,-_._..'--_.._------ Company: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: 4 Field: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek #1, True North Site: Falls Creek location Vertical (TV D) Reference: Current Drilling 266.0 Well: Falls Creek #1 Section (VS) Reference: Well (0.00N,O.00E,270.00Azi) Wellpnth: Sidetrack Survey Calculation Method: Minimum Curvature Db: Sybase ----._--_.- .~___·._A~~·..·.___··__.,__~".____.__._'_,_____~ --_.",._-~,._.__.._---_._~,"--_._-,~---_.-..~_._."--,,-.-.--- Survey: Gyro Survey of Sidetrack -----_....-._-".._-,.~._-----,-_._..,._-------..._--_._...-.-.-....-.....---.--.----..-,---.--,-.-.-..,.....---.,~_.,_._.."._----_._--~._.__._.._._-----_._--...-,--~---.~,_..--,--_..-........__._----_.__.._._.__.._. _···____···_·___n···____._.··_ MD loci Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft '.'~~------_._"~-'-~-'-~- __.__~___"~"4..__..._..".__,__~. 5148.72 30.26 271.89 4645.86 -67.94 -1634.10 1634.10 2.62 -2.45 -1.81 NS Gyro 5180.15 30.16 271.85 4673.02 -67.42 -1649.90 1649.90 0.32 -0.32 -0.13 NS Gyro 5211.57 28.93 269.68 4700.35 -67.21 -1665.39 1665.39 5.19 -3.91 -6.91 NS Gyro 5242.99 28.72 270.38 4727.88 -67.20 -1680.54 1680.54 1.27 -0.67 2.23 NS Gyro 5274.41 27.60 269.53 4755.58 -67.21 -1695.37 1695.37 3.79 -3.56 -2.71 NS Gyro 5305.84 27.14 270.61 4783.49 -67.19 -1709.82 1709.82 2.15 -1.46 3.44 NS Gyro 5337.26 25.74 269.82 4811.62 -67.14 -1723.81 1723.81 4.59 -4.46 -2.51 NS Gyro 5368.68 25.12 269.51 4840.00 -67.22 -1737.30 1737.30 2.02 -1.97 -0.99 NS Gyro 5400.10 24.12 270.08 4868.56 -67.26 -1750.39 1750.39 3.27 -3.18 1.81 NS Gyro 5431.53 23.72 269.89 4897.29 -67.27 -1763.13 1763.13 1.30 -1.27 -0.60 NS Gyro 5462.95 22.60 269.85 4926.18 -67.30 -1775.49 1775.49 3.56 -3.56 -0.13 NS Gyro 5494.37 22.44 270.31 4955.21 -67.28 -1787.52 1787.52 0.76 -0.51 1.46 NS Gyro 5525.79 22.33 268.50 4984.26 -67.40 -1799.49 1799.49 2.22 -0.35 -5.76 NS Gyro 5549.26 21.93 269.16 5006.00 -67.58 -1808.32 1808.32 2.02 -1.72 2.81 Target 1 5557.22 21.79 269.39 5013.39 -67.62 -1811.29 1811.29 2.02 -1.71 2.88 NS Gyro 5588.64 20.76 267.70 5042.67 -67.91 -1822.68 1822.68 3.81 -3.28 -5.38 NS Gyro 5620.06 20.38 267.67 5072.08 -68.35 -1833.71 1833.71 1.21 -1.21 -0.10 NS Gyro 5651.48 19.80 268.16 5101.59 -68.75 -1844.50 1844.50 1.92 -1.85 1.56 NS Gyro 5682.91 19.34 268.74 5131.21 -69.03 -1855.02 1855.02 1.59 -1 .46 1.85 NS Gyro 5714.33 18.57 268.21 5160.92 -69.30 -1865.22 1865.22 2.51 -2.45 -1.69 NS Gyro 5745.75 17.99 268.21 5190.76 -69.61 -1875.08 1875.08 1.85 -1.85 0,00 NS Gyro 5777.17 17.22 267.33 5220.70 -69,98 -1884.57 1884.57 2.59 -2.45 -2.80 NS Gyro 5808.60 16.51 266.94 5250.78 -70.43 -1893.68 1893.68 2.29 -2.26 -1.24 NS Gyro 5840.02 15.60 266.79 5280.98 -70.91 -1902.35 1902.35 2.90 -2.90 -0.48 NS Gyro 5871.44 15.66 267.65 5311.23 -71.32 -1910.81 1910.81 0.76 0.19 2.74 NS Gyro 5902.86 15.69 268.23 5341 .49 -71.62 -1919.29 1919.29 0.51 0.10 1.85 NS Gyro 5934.29 15.55 268.86 5371.75 -71.84 -1927.75 1927.75 0.70 -0.45 2.00 NS Gyro 5965.71 15.37 269.75 5402.04 -71 .94 -1936.13 1936,13 0.95 -0.57 2.83 NS Gyro 5997.13 14.81 269.98 5432.37 -71.96 -1944.31 1944.31 1.79 -1.78 0.73 NS Gyro 6028.55 14.82 269.72 5462.75 -71.98 -1952.34 1952.34 0.21 0.03 -0.83 NS Gyro 6059.98 13.56 271.68 5493.22 -71.89 -1960.04 1960.04 4.29 -4.01 6.24 NS Gyro 6091 .40 13.40 271.34 5523.78 -71.70 -1967.37 1967.37 0.57 -0.51 -1.08 NS Gyro 6122.82 13.09 271.06 5554.36 -71.55 -1974.56 1974.56 1.01 -0.99 -0.89 NS Gyro 6154.24 12.21 269.56 5585.02 -71.51 -1981.44 1981.44 2.99 -2.80 -4.77 NS Gyro 6185.67 12,07 270.30 5615.74 -71.52 -1988.05 1988.05 0.67 -0.45 2.35 NS Gyro 6217.09 11.95 270.60 5646.48 -71.47 -1994.59 1994.59 0.43 -0.38 0.95 NS Gyro 6248.51 11.41 269.99 5677 .25 -71.43 -2000.95 2000.95 1.76 -1.72 -1.94 NS Gyro 6279.93 10.18 268.43 5708.11 -71.51 -2006.83 2006.83 4.02 -3.91 -4.96 NS Gyro 6311.36 9.50 268.39 5739.08 -71.66 -2012.20 2012.20 2.16 -2.16 -0.13 NS Gyro 6342.78 9.12 268.31 5770.08 -71.80 -2017.28 2017.28 1.21 -1.21 -0.25 NS Gyro 6374.20 9.08 269.85 5801.11 -71.88 -2022.25 2022.25 0.79 -0.13 4.90 NS Gyro 6405.62 9.09 269.17 5832,13 -71.93 -2027.21 2027.21 0.34 0.03 -2.16 NS Gyro 6437.05 8.83 269.47 5863.18 -71.98 -2032.11 2032.11 0.84 -0.83 0.95 NS Gyro 6468.4 7 7.69 266.95 5894.27 -72.12 -2036.62 2036.62 3.81 -3.63 -8.02 NS Gyro 6499.89 7.48 268.67 5925.42 -72.28 -2040.76 2040.76 0.98 -0.67 5.47 NS Gyro 6531.31 7.66 269.68 5956.56 -72.34 -2044.90 2044.90 0.71 0.57 3.21 NS Gyro 6562.74 7.42 270.81 5987.72 -72.32 -2049.03 2049.03 0.90 -0.76 3.60 NS Gyro 6594.16 6.31 270.78 6018.92 -72.27 -2052.78 2052.78 3.53 -3.53 -0.10 NS Gyro 6625.58 5.72 271.65 6050.16 -72.20 -2056.07 2056.07 1.90 -1.88 2.77 NS Gyro 6657.00 5.57 273.86 6081 .43 -72.05 -2059.16 2059.16 0.84 -0.48 7.03 NS Gyro 6688.43 5.45 275.59 6112.72 -71.80 -2062.17 2062.17 0.65 -0.38 5.50 NS Gyro 6719.85 5.46 279.27 6143.99 -71.42 -2065.13 2065.13 1.11 0.03 11.71 NS Gyro 6751.27 5.54 280.70 6175.27 -70.90 -2068.09 2068.09 0.51 0.25 4.55 NS Gyro 6782.69 5.85 279.38 6206.53 -70.35 -2071.16 2071.16 1.07 0.99 -4.20 NS Gyro ---,---- -~-----_._-_._----_.'--~----~-,,-_.._---~-- -.,.- -----------.-..,--- ) ) Survey Report ...~..._------.,._--"'_.__._~_.__.~-_....----_.~~'"-_._-----,-.---.--.----.--.. . .... ..._.,-_._.._..-.._-~ .._·__.____________,,_..__..___w.,_"._~"'_~_ ._~_.,_._~__....._.._..u,_. Company: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: 5 Field: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek #1, True North Site: Falls Creek location Vertical(TVD) Reference: Current Drilling 266.0 Well: Falls Creek #1 Section (VS) Reference: Wel/(O. OON ,0 .00E,270. OOAzi) WelIpath: Sidetrack Survey Calculation Method: Minimum Curvature Db: Sybase .__._.._._-----~_._._---_._-_._.~...__.- ._~._--_._..__.~. Survey: Gyro Survey of Sidetrack --.-.--...-..-----.-.-----.-.....---.---.--.-----.---.-..._.".-..-..~....._.._._-----_.".-..__.._._._..-.._------..--.--...-----.-.--..-.----..... ...----.---.------...'-.-- MD IncI Azim TVD +N/-S +E/-W VS DLS Build Turn TooVComment ft deg dsg ft ft ft ft deg/100ft deg/100ft deg/100ft _.w_,__..____~y___~~_. ··_,,_·__,_·'_____4_._____··________~_"'_._,_._____~._~~,_~_ ... 6814,12 5.98 280.71 6237,80 -69.79 -2074.35 2074.35 0.60 0.41 4,23 NS Gyro 6845.54 6.06 281.48 6269,04 -69.15 -2077.58 2077 .58 0.36 0.25 2.45 NS Gyro 6876.96 6.11 282.42 6300,29 -68.46 -2080.84 2080.84 0.35 0.16 2.99 NS Gyro 6908.38 5.18 279.93 6331.55 -67.86 -2083.87 2083.87 3.06 -2.96 -7.92 NS Gyro 6939.81 4.66 275.84 6362.87 -67.48 -2086.54 2086.54 1.99 -1.65 -13.01 NS Gyro 6971,23 4.86 273.80 6394.18 -67.27 -2089.14 2089.14 0.83 0.64 -6.49 NS Gyro 7002.65 4.69 270.94 6425.49 -67.16 -2091.75 2091.75 0.93 -0.54 -9.10 NS Gyro 7034.07 4.55 261.20 6456.81 -67.33 -2094.27 2094.27 2.53 -0.45 -31.00 NS Gyro 7065.49 4.79 259.75 6488.12 -67.75 -2096.79 2096.79 0.85 0.76 -4.61 NS Gyro 7096.92 4.94 261 .40 6519.44 -68.19 -2099.42 2099.42 0.65 0.48 5.25 NS Gyro 7128.34 4.79 259.67 6550.75 -68.62 -2102.05 2102.05 0.67 -0.48 -5.51 NS Gyro 7159.76 4.49 254.17 6582.06 -69.20 -2104.52 2104.52 1.71 -0.95 -17.50 NS Gyro 7191.18 4.11 255.74 6613.40 -69.81 -2106.80 2106.80 1.27 -1.21 5.00 NS Gyro 7222.61 2.93 254.14 6644.77 -70.31 -2108.66 2108.66 3.77 -3.75 -5.09 NS Gyro 7254.03 2.63 254.25 6676.15 -70.72 -2110.13 2110.13 0.95 -0.95 0.35 NS Gyro 7285.45 2.73 252.86 6707.54 -71.14 -2111 .54 2111.54 0.38 0.32 -4.42 NS Gyro 7316.87 2.79 252.40 6738.92 -71.59 -2112.98 2112.98 0.20 0.19 -1.46 NS Gyro 7348.30 2.75 254.44 6770.31 -72.02 -2114.43 2114.43 0.34 -0.13 6.49 NS Gyro 7379.72 2.72 258.00 6801.70 -72.38 -2115.89 2115.89 0.55 -0.10 11.33 NS Gyro 7411.14 2.76 260.72 6833.08 -72.66 -2117.37 2117.37 0.43 0.13 8.66 NS Gyro 7442.56 2.89 261 .43 6864.46 -72.90 -2118.90 2118.90 0.43 0.41 2.26 NS Gyro 7473.99 2.97 261.83 6895.85 -73.13 -2120.48 2120.48 0.26 0.25 1.27 NS Gyro 7505.41 2.83 261.05 6927.23 -73.37 -2122.06 2122.06 0.46 -0.45 -2.48 NS Gyro 7536,83 2.15 250.49 6958.62 -73.68 -2123.38 2123.38 2,60 -2.16 -33.61 NS Gyro 7568.25 1.56 236.43 6990.02 -74.12 -2124.29 2124.29 2.36 -1.88 -44.75 NS Gyro 7599.68 1.54 235.07 7021 .44 -74.60 -2124.99 2124.99 0.13 -0.06 -4.33 NS Gyro 7631,10 1.46 235.47 7052.85 -75.06 -2125.67 2125.67 0.26 -0.25 1.27 NS Gyro 7662.52 0,90 231.71 7084.27 -75.44 -2126.19 2126.19 1.80 -1.78 -11.97 NS Gyro 7693.94 0.84 234.34 7115.68 -75.73 -2126.57 2126.57 0.23 -0.19 8.37 NS Gyro 7725.37 0.87 231.69 7147.11 -76.01 -2126.95 2126.95 0.16 0.10 -8.43 NS Gyro 7756.79 0.79 237.98 7178.53 -76.28 -2127.32 2127.32 0.39 -0.25 20,02 NS Gyro 7788.21 0.69 238.91 7209.94 -76.49 -2127.66 2127.66 0.32 -0.32 2.96 NS Gyro 7819.63 0.40 227.94 7241.36 -76.66 -2127.91 2127.91 0.98 -0.92 -34.91 NS Gyro 7851.06 0.11 270.33 7272.79 -76.73 -2128.02 2128.02 1.04 -0.92 134,87 NS Gyro 7882.48 0.17 343.02 7304.21 -76.69 -2128.06 2128.06 0.55 0.19 231.35 NS Gyro 7913.90 0.19 323.93 7335.63 -76.60 -2128.11 2128.11 0.20 0.06 -60.76 NS Gyro 7945.32 0.25 258.65 7367.05 -76.57 -2128.21 2128.21 0.77 0.19 -207.77 NS Gyro 7976.75 0.28 302.50 7398.48 -76.55 -2128,34 2128.34 0.64 0.10 139.52 NS Gyro 8008.17 0.24 291.05 7429.90 -76.48 -2128.46 2128.46 0.21 -0.13 -36.44 NS Gyro 8039,59 0.40 312.05 7461.32 -76.38 -2128.61 2128.61 0.62 0.51 66.84 NS Gyro 8071.01 0.38 322.14 7492.74 -76.23 -2128.75 2128.75 0.23 -0.06 32.11 NS Gyro 8102.44 0.30 346.56 7524.17 -76.07 -2128.83 2128.83 0.52 -0.25 77.70 NS Gyro 8133.86 0.32 345.48 7555.59 -75.90 -2128.88 2128.88 0.07 0.06 -3.44 NS Gyro 8165.28 0.39 329.81 7587.01 -75.72 -2128.95 2128.95 0.38 0.22 -49.87 NS Gyro 8196.70 0.21 308.95 7618.43 -75.59 -2129.05 2129.05 0.66 -0.57 -66.39 NS Gyro 8228.13 0.16 205.25 7649.86 -75.60 -2129.11 2129.11 0.93 -0.16 -329.94 NS Gyro 8259.55 0.23 221.08 7681 .28 -75.68 -2129.17 2129.17 0.28 0.22 50.38 NS Gyro 8290.97 0.23 244.11 7712.70 -75.76 -2129.27 2129.27 0.29 0.00 73.30 NS Gyro 8322.39 0.31 242.09 7744.12 -75.83 -2129.40 2129.40 0.26 0.25 -6.43 NS Gyro 8353.82 0.55 262.55 7775.54 -75.89 -2129.63 2129.63 0.89 0.76 65.10 NS Gyro 8385.24 0.43 267.60 7806.96 -75.91 -2129.90 2129.90 0.41 -0.38 16.07 NS Gyro 8416.66 0.37 283.00 7838.38 -75.89 -2130.11 2130.11 0.39 -0.19 49.01 NS Gyro 8448.08 0.58 306.73 7869.80 -75.78 -2130.34 2130.34 0.90 0.67 75.53 NS Gyro , ----,---..-,-~-----.---------. "---'--'-'------" ---.-------- ----------....-- -.-~.-.----------_. -~..._.""-______._______ __________._..___.._..._.___,__._____..____.._.____--4 ) ) Survey Report ..._---~.__._~--_._----_._----_..,_._-,--~-----_..-,_...--._._,,-~--_..__..---_._,.,,_.._..,-_.._._--._- ~,-,--,"---_..~.......__.,...__.-...._- Company: Marathon Oil Company Date: 2/27/2002 Time: 09:34:15 Page: 6 Field: Falls Creek Co-ordinate(NE) Reference: Well: Falls Creek#1, True North Site: Falls Creek location Vertical (TVD)· Reference: Current Drilling 266.0 Well: Falls Creek #1 Section (VS) Reference: Well (0 . OON ,0 .00E,270 .00Azi) Wellpath: Sidetrack Survey Calculation Method: Minimum· Curvature Db: Sybase -..-..-------..-----.--.....--.- -_._--._---~-~---"-------~- Survey: Gyro Survey of Sidetrack ----..---.....-..-.--...-----.-----.--,..-..... -....---.--...-..----...- _.._-._------,_...------_.__.~-------_._.._-._'._._-- ..-.--------.-..-----..--".-.-- MD IncI Azim TVD +N/-S +E/-W VS DLS Build Turn TooVComment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft ---_.....----,-------"----,.__.,-,.~----~--~._---,.._--._.__.._---_.._~---- --,---------_..._--~----------- .-.------ 8479.51 0.67 307.18 7901.23 -75.57 -2130.61 2130.61 0.29 0.29 1.43 NS Gyro 8510.93 0.91 306.09 7932.65 -75.31 -2130.96 2130.96 0.77 0.76 -3.47 NS Gyro 8542.35 1.32 302.10 7964.06 -74.97 -2131.47 2131.47 1.33 1.30 -12.70 NS Gyro 8573.77 1.32 301.66 7995.47 -74.59 -2132.08 2132.08 0.03 0.00 -1.40 N S Gyro 8605.20 1.50 297.48 8026.89 -74.21 -2132.76 2132.76 0.66 0.57 -13.30 NS Gyro 8636.62 1.62 303.18 8058.30 -73.78 -2133.49 2133.49 0.62 0.38 18.14 NS Gyro 8668.04 1.77 300.56 8089.71 -73.29 -2134.28 2134.28 0.54 0.48 -8.34 NS Gyro 8699.46 1.73 301.79 8121.11 -72.79 -2135.10 2135.10 0.17 -0.13 3.91 NS Gyro 8730.89 2.00 307.02 8152.53 -72.21 -2135.94 2135.94 1.01 0.86 16.64 NS Gyro 8762.31 2.13 312.27 8183.93 -71.49 -2136.81 2136.81 0.73 0.41 16.71 NS Gyro 8793.73 2.19 311.53 8215.32 -70.70 -2137.70 2137.70 0.21 0.19 -2.36 NS Gyro 8825.15 2.30 314.78 8246.72 -69.85 -2138.59 2138.59 0.54 0.35 10.34 NS Gyro 8856.58 2.29 314.65 8278.12 -68.97 -2139.49 2139.49 0.04 -0.03 -0.41 NS Gyro 8888.00 2.43 317.47 8309.52 -68.04 -2140.38 2140.38 0.58 0.45 8.98 NS Gyro 8900.00 2.43 317.47 8321.51 -67.66 -2140.73 2140.73 0.00 0.00 0.00 NS Gyro ----..--.----.---.-..----- --~,_.._..~._----_.__..."._-----_.._-_..- Targets - _.._..__.__._~_..._.-.~._._._.~_._.-.._--,_. ~_..~-.._.__."'-...._,-_.._._. .....__...._-_._,,-_.~.._.~...~_._----_.----_....__....-..._....._..~.._--~"..,_.._..._._--_.- .. ----,--,-_._..._._~---.~-~_.__.._~--".._.._._---,,_._...... Name DescriptiQn TVD ft 5006.00 +N/-S +E/-W ft 0.00 -1750.00 Map Map Northing Easting ft ft --_._~._._..._--_.__.__..~,---- 2269488.09 238190.51 60 12 15.856 N <~-- Latitude ----> <--- ·L()ngitude.~~ Deg . Min Sec Deg Min Sec Target 1 151 26 20.948 W -_....__..-..-----.,~_._._--_._-._-_. -.--..-,.--...---. .... ----. _. --_.~--_.._._.._--. ..-.....-.-'-- ..-----.-- ..---..... ..._._._~-,,--._---_. ------~~_._- Falls Creek # 1 RD Completion Operational History Subject: Falls Creek #lRD Completion Operational History Date: Thu, 2 May 200209:22:09 -0800 From: "Walsh, K D (Ken)" <KDWalsh@MarathonOi1.com> To: "Steve Davies (E-mail)..<Steve_Davies@admin.state.ak.us> CC: "Tom Maunder (E-mail)..<Tom_Maunder@admin.state.ak.us> Steve, Attached please find the morning reports for the completion activities at the Falls Creek #1 RD well as per your request. Also attached is the PTS flow test report for the well. Marathon Oil requests your cooperation in maintaining the confidentiality of this information. Please let me know if you need additional information. Ken Ken D. Walsh Advanced Production Engineer Alaska Business Unit , 907/564-6305 (work) , 907/268-5660 (pager) , 907/240-0568 (cell) Ê 907/564-6489 (fax) Q r:9 kdwalsh@marathonoil.com «020407FC#1 RD.xls» «020408FC#1 RD.xls» «020409FC#1 RD.xls» «Falls Creek#12.xls» i'~_mnl!llvd''+'+W·'''''''''''''''·'' """~LL ...~n:_Ul_iLmll~I'III"LUI'ltlr"" ..·..m. ,I IIHUI/II'..flo'oli'l 11.11'.....\: IIJI.InYolIIII'III'1/JI)/ "'~ :11iII',IIL I: \il1I1'. 1','..:1111I1 1110I11o'OI.1 _.:1. .l1II1'I!'m'glIIHIIII.' _rlln~"·"·:lIIa'm'Hi'lllm}:lmIBllmmllmll~\ojI·' ::+l':lImW......· ~V\.WW·'llillll(Jf',UI, .::lImWH:L. _IIHUl1¡'mlllllmllmmg:'1oI'II"'I'II: ! 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Re: Falls Creek #1 RD: Termination of Well Cú.\.'\'~tion. ) Subject: Re: Falls Creek #1 RD: Termination of Well Completion. Date: Fri, 19 Apr 2002 14:52:59 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Walsh, K D (Ken)" <KDWalsh@MarathonOil.com> CC: Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, John D Hartz <jack_hartz@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> ') 0-D\ - \ s S-. Ken, We acknowledge receipt of your proposal with regard to terminating the current testing program on the Falls Creek #1 RD. Your plan to delay the 4 point testing until a pipeline connection is available is acceptable. The requirement of 25.225 is "...multi-point testing...prior to regular production." With regard to securing the well, please provide the details of the securing method(s). We would also appreciate an estimate (although likely crude) of how long the well will be awaiting connection. Congratulations on the well. Tom Maunder, PE AOGCC "Walsh, K D (Ken)" wrote: Tom, Marathon Oil Company requests permission from the AOGCC to terminate well testing on the Falls Creek #1 RD well. This well is a sidetrack of the Falls Creek #1 and has been perforated in the Tyonek T3 interval (8714'-8750' MD). After the well was perforated, the interval was flow tested briefly and then shut in immediately following receipt of a complaint by a local resident(s) concerning the noise associated with the hydrocarbon gas venting from the test stack. Marathon Oil was not able to secure a four-point production test due to the early cessation of the test to accommodate the residents. Marathon requests that the well remain shut-in until tie-in to the proposed KKPLpipeline is complete. It is proposed that a four-point test be conducted into the pipeline rather than the test stack following startup of production. It is requested that the AOGCC provide an email responsetokdwalsh@marathonoil.com:;onfirming that this request has been approved. It is understood that Marathon will immediately follow up this email request with a signed letter request including paper copies of the well completion report, wellbore diagram, and flow test report. Please contact Ken Walsh at the following telephone numbers or by email should you need additional information. I appreciate your past help and look forward to hearing from you. Ken Ken D. Walsh Advanced Production Engineer Alaska Business Unit , 907/564-6305 (work) , 907/268-5660 (pager) , 907/240-0568 (cell) Ê 907/564-6489 (fax) ~ s;1 kdwalsh@marathonoil.com Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 1/18/20031:46 PM FROM N I N I LCH I K GE"IERAL STORE= ) FAX NO. : 907+567+1091 ') Apr. 04 2002 12: 09PM P2 h v,~~ ,~t Re-ènter Suspended We" _."~. é?.......~ Time E1dansÎòn stimYlate ~ -<5 STATE OF ALASKA ALASKA Ofl AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reque~t Abandon After Casing Change Approved Program Suspend _ Operati~m Shutdown Repç¡ir W@I!_ Plugging_ Pull· Tubing............. Vañance .............-.... 'Iou" 5. Type of WeD; Development exploratory x Stratigraphie = Sefviçe - . ... ..~..' . 2. Name of Operawt MARATH.a~.9L COMPANY 3. Address'''' . ..", . .....,. P. o. Box 1'geJ~, Af1chora~,', ~~..Jt95-19-61G8 ../.. "4. L~ti()n ofweifat ~œ 1898' FSL & 2$35' F=(:L, SéC. 6. T1N, R12W, SM At top of ProQuctiv4;!' 1~r'VaJ 1821' FSl & 501.3.' FEl, ~ec. 6, T1N, R12.W, SM " ..". ...... At E~~ 0ep1h li"ot.~~.~~ëatj~~ to'''vënt:~~~ ~,~~ng well ~~".... At Tot,d Depth , 1~·. f~!-,! & 202S' F~L. ~..6~..IJN. R12W, ~.,..., . . 12. Present w.eft,'CondIIlOn Summæ:y T~~I [\~p1h: .. m~~~I.~d true vertical EffeëW~ Dep1h: mêèW'I"Qd true verlicaI CS\3Ïf1g Sb"ucturaJ' Conductor SurfaCe Intermediate Production Liner PElrlOr~1ion Depth: (P'toposod) let\gth 2S" 248' 24$Si 6600' 8900' measured 8114'..8'150" Ssþf Vue V$1j¢3 6136'008172' Sspf Tubing (size. grade, and rnesstJrad dêpth) Packers and SSSV (type and mea$UÆd d$pth) '1r-Attåchments .. . MOO re~t 8322 feet 3900 feet 8322 feet Size 36" 20" 1WS" 9-51811 4/112" Cemented DfNen 480 !jIk!¡¡' 166u ~ 1884 sks 1052 sics Measured Depth 28' 248' 245$' 8600' 8900' Tnre V~bl Depth 2sT 248' 2440' 8321' 83,":2~ 7908'·7936' S$pf 1328'"7"'" &5pf NIA. NlA ...."...."........~... .. ...··_·.._··_...~._...A_..~'__._.____ . OesmptiQI't SUmmary of Proposaf 15, Status of WeD ClassIfieadon as: Detailed Operations Program L . '~""'~ ...... ..~. '''",'' .. . '14. Estimated Oste for Commencmg·õPeiätiOO· . 4rr/2002 . . ............. ..._-,,- '16. ifPropœal waS Vërbalty APProved . ..'".....~........--.- 011_ Gas X Petfor~te X Otti!!.'r . . 6. Da1.U1't\ Elevation (DF Of K8) RKB¡;;; 27a feet .--. 7: Unit or PropeftÿNa'me ~ . ....r:.~1Is Creek . 8, We" Number , , - !.. ,._ ~ans Creefc; ¡t1rd . ~9. pêJmit Numbëf' --......,,-.. ; _,_~~~J.~~,...._,.._"."., .... .10. APi Number 00- 133-1 OOO!)..O 1 . '11, F~oof ..+..." .. I_~_I.'·(.\.~'- W·~"A'IM,\fII,W~,jII. Wddc::at RECEIVED APR 0 4 2002 Alaska Oil & Gas Cans. Commíssion Anchorage Wellbore bi8gï;m'''''''' .... Suspended Namê of Approver Date Approved SefViœ ."..,. 17. I hereby certifY thatth~' fOrêgOing IS tru~ and correct to tt1el)ëstofmy·k~~dgë..:·"m... ..__u . ~..d t~_~ ~~~ KònD.~~~~~~~:_ _ Dale Conditions. of AppS'ov'id: Notify Comm~J\SC)representative may witness ~Q~\ t.A;,\" ~~~~,,_i IAppcOYð, I.NO-. ::;)_ Plug Integrily _ BOP Test X- LOOàtioR ~ _ ,_ _ ~C·co!-. .-:-//(..; , Mecl'lànieallntegñty Test _ S~I"iII'Mt I::'nrm ~"'aukeQ ¥!v I..\, ()~ '~p~~d by Order of tha Com~~~n Fònn 1 0-403 ~ev. 06115188 ~._.,:. ~QìdaIIf TIfIar ...:~ ! ("\ r'") ! ¡ ~..,' \.j í \ 4'112002 Comm~oner ~ ;¡j¿i~ L ) ) MARATHON OIL COMPANY ALASKA REGION Wildcat Field Falls Creek #1 RD Testing Procedure WBS # RW.01.G0313.CAP.CMP Tyonek Completion Procedure (01-March-02) All DATA RELATIVE TO THE TESTING OF THIS WEll IS CONFIDENTIAL. Note: The sidetrack of the original hole has been drilled, cased, and cemented. The drilling rig has been demobilized from the pad and a single master valve with a well cap has been installed. The back pressure valve has been removed from the wellhead. The 4-1/2" casing has been tested to 3500 psi surface with KCL water. The 4-1/2" x 9-5/8" annulus has been tested to 1000 psi with a 10.5 ppg cement spacer. 1. Vetco to set 2-way check in back pressure valve profile. NU 4-1/16" 5K tree with double master, flow cross, swab, wing valve, and SSV. Pressure test tree to 250/5000 psi. Haul forklift, air compressor, generator, frost fighter, portable toilet, and two light plants to location. 2. MIRU PTS well testers. NU 4-1/1611, 5K companion flange with 3" LP outlet threads (MOC) to SSV on tree. Lay flow lines to separator and vent stack. Plumb in methanol injection line to flow back line and air lines to SSV. Ensure that SSV has a lock open plug and a needle valve attached. Load separator with 50:50 glycol water mixture which was removed from separator with a vac truck prior to transportation. 3. RU Pressure test pump and 100% methanol tote to 'X" 00 downhole chemical injection system and pressure up to 5,000 psig to shear injection port and actuate check valve. 4. MIRU Pollard Slickline Service with 0.125" 00 wire. Hold Safety and environmental awareness meeting. Perform wire twist test. Install 4" lubricator. Pressure test lubricator to 2,000 psig using #1 diesel. Bleed diesel pressure off lubricator into PTS flowback line. PU tool string consisting of weight bars, roller stem, oil jars, and spang jars. RIH w/3.75" gauge ring to 8851' (top of float collar, measured depth). Record PBTD tag depth. Correlate PBTD depth to 4-1/2" "X" profile nipple (3.813" ID) at 5387' MD. 5. Hold PJSM. MIRU BJ Services 1-3/4" coil tubing unit and nitrogen pumper. Have Veco crane pick up BJ coil tubing BOP. Make up BOP to top of 4" Bowen connection on swab valve. Place coil tubing in injector head. Make up lubricator to injector head. Pick up injector head and lubricator with crane. Install slick wash nozzle on end of coil tubing and make proper pull test. Make up CT injector head and lubricator to BOP's. Pressure test CT BOP pipe and blind rams with 50/50 methanol water to 3500 psi max pressure. Pressure test flowback iron to 3500 psi. Displace methanol water in coil tubing to flowback tank with nitrogen. 6. Open well and RIH with coil tubing to PBTD unloading KCL water through PTS line to flowback tank with nitrogen. POOH with coil tubing trapping 1730 psi nitrogen pressure at the wellhead (1500 psi (41%) underbalance at formation TVD). RDMO BJ Services coil tubing and nitrogen units. TEST #1 8714' Sand Total 8714' -8750' 36' NOTE: The SBHP \. )is T -3 sand is approximately 3661 psi, )45 psi/ft gradient) at 8136' TVD. 7. RU Schlumberger wireline service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Have on location the appropriate centralizers and roller stem to allow passage of tools to TD. Hold safety and environmental awareness meeting. PU and RIH with Gun GR and 3.375" HSD guns loaded 6 SPF 60 degree-phased with PJ 3406 HMX 22.7 gram charges to perforate 8714'-8750' MD. API target (5,713 psi) performance is 0.45" entrance hole and 38.6" penetration. Run GR/CCL correlation strip log from PBTD to 4000' MD correlating GR with Platform Express open hole log run 15-Aug-2001. RDMO Schlumberger wireline. Note 4-1/2" "X" profile nipple (3.813" ID) at 5387' MD. Correlate depth to Schlumberger open hole logs dated 15-Aug-2001. RD Schlumberger wireline. 8. Flow test well. Once stabilized flow is attained, it is recommended to attempt to establish stabilized flow with 1500 psi FCP. The unloading rate up 4-1/2" casing is 5.6 MMCFGPD @ 1,500 psig FCP (1800 psi at perfs). Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with transient test questions Paul Williams 907-564-6403. Following clean up and constant gas rate, prepare for pressure transient work. NO FLOW CONTINGENCY (Steps #9 & #10 ) If wellbore does not flow, proceed to Step #9. If well flows, proceed to Step #11. 9. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to 3,000 psi. RIH with stand and tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 8732' mid perf. COH making same gradient stops. RD slickline equipment. 10. RU BJ Services CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at later time, if necessary. 12. Resume flow test of well as outlined above. a. Test is expected to consist of a 24-48 hour stabilized flow period. b. A PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. c. If a PBU is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to wellhead gas pressure. RIH w/tandem quartz electronic gauges on AO Slip Stop and set at 8760' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. TEST #2 7908' Sand Total 7908'-7935' 27' NOTE: The SBHP of this T -3 sand is approximately 3299 psia (0.45 psi/ft gradient) at 7330' TVD. 13. Trap 1650 psi gas pressure or apply 1500 psi nitrogen at wellhead to allow 40% underbalance while perforating. RU Schlumberger wireline service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Have on location the appropriate centralizers and roller stem to allow passage of tools to TO. Hold safety and environmental awareness meeting. PU and RIH with 3.375" HSD guns loaded 6 SPF 60 degree-phased with PJ 3406 HMX 22.7 gram charges to perforate 7908'-7935' MD. API target (5,713 psi) · . performance is 0.4t )rance hole and 38.6" penetration. Corre )depth with GR/CCL run in Step #7. RDMO Schlumberger wireline. 14. Flow test well to unload liquid. No more than a 50% drawdown (1375 psi flowing WHP) is permitted for this interval. Once stabilized flow is attained, it is recommended to attempt to establish stabilized flow with 1375 psi FCP, The unloading rate up 4-1/2" casing is 5.3 MMCFGPD @ 1,375 psig FCP. Consult Anchorage office D. Brimberry for drawdown limitations 907-564-6402. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Anchorage engineering with transient test questions Paul Williams 907-564-6403. Following clean up and constant gas rate, prepare for pressure transient work. NO FLOW CONTINGENCY (Steps #15 & #16 ) If wellbore does not flow, proceed to Step #15. If well flows, proceed to Step #17. 15. RU Slickline company. Hold Safety and environmental awareness meeting. Pressure test lubricator to wellhead pressure. RIH with tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 7922' mid perf. COH making same gradient stops. RD slickline equipment. 16. RU BJ Services CT and nitrogen unit. Hook up flowback iron. Fully function and pressure test BOP and rams. RIH w/slick nozzle and jet well to unload liquid. Exact CT procedure will be defined at later time, if necessary. 17. Resume flow test of well as outlined above. a. Test is expected to consist of a 24-48 hour stabilized flow period. b. A PBU may be elected to determine permeability, skin, pressure, and commercial viability of Tyonek Interval including stimulation potential. c. If a PBU and 4-pt. test is ordered, RU Pollard slickline. Hold Safety and environmental awareness meeting. Pressure test lubricator to wellhead gas pressure. RIH w/tandem quartz electronic gauges on AO Slip Stop and set at 7945' MD. Connect SPIDR to wellhead to gather surface data. RD slickline equipment. 18. Following completion of testing. Lubricate in BPV's and winterize tree. Chain closed the master valves and secure location. RDMO well testers. Release rental equipment and return to vendors. Pt..,Ç)\~~~S>'Ð'{-~1 ~~('..\)~C1\>'" ~\~ ~ CONTACTS .\\) \'?Ð~ \-~c:;.Q~c;. 'Ñ( O. s~~~ t~ Q~~{ Ken Walsh: 907-564-6305 (w) David Brimberry: 907-564-6402 (w) ~s~t'--t "> 907-268-5660 (p) 907-231-0630 (p) ~_\ _ CJ::) ~ \~ \1<::: 907-564-6403 (w) J/) 'lrvl l:.{(,\ Gary Eller: 907 -564-6315 (w) 907 -268-0411 (p) Paul Williams: Weichun Chu: 303-794-3863 (w) Ben Schoffmann: 907 -564-64 71 (w) Wayne Cissell: John Gilbert: 907 -283-1308 (w) 907-262-3620 (p) 713-296-2981 (w) aO 1-/55 Alaska l )ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 6, 2002 Ms. Lisa Weepie Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 VIA CERTIFIED MAIL RE: Marathon Falls Creek #lrd CONFIDENTIAL Dear Lisa: Enclosed are the following data for the above referenced well: Directional Survey Data................................................................. Paper / Digital Final reference elevations are as follows: KB = 267' above MSL GL = 244.6' above MSL Please note that this directional data replaces incorrect data that was previously submitted to A OGCc. Digital Well Logs: Array Induction, Density Neutron, Gamma Ray **Platform Express** Repeat Formation Tester, Gamma Ray Best-DT*, Sonic Processing Density, Neutron Logs, Gamma Ray **Platform Express** Please review the enclosed data, sign and return one copy of this transmittal. Thank you, ~~ Kaynell Zeman Exploration Aide Enclosures Receipt: 7001 03200005 15795124 Received ~ ~ Date: Environmentally aware for the long run. ()/I '6- 6~ ~'17e^,/J;'~ e()M"""~>/~ JH ùI~'7f 71i. ~ f-' L /(7 AlaskaE ~ssUnit ( ) . ~ /. t/ 79~ ·"/255- !It'tN~ ðt(~ ~/ Marathon Oil Company February 20, 2002 Geological Materials Center Attn: John Reeder 18205 Fish Hatchery Road Eagle River, p...K 99577-2805 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 .., 5"ttf-¿ J{)' PI- Y , LETTER OF TRANSMITAL Hand Delivered RE: Marathon Oil Company Falls Creek Unit #lRD Dry Samples Enclosed are the following samples collected from Marathon's Falls Creek Unit #lRD well. Please keep the data confidential at this time. Depth From (Feet) 3,094 4,360 5,500 6,340 6,870 7,400 7,990 8,540 Dry Samples Depth To (Feet) 4,360 5,500 6,340 6,870 7,400 7,990 8,540 8,900 Box No. 1 2 3 4 5 6 7 8 ;} à } - / ~r if )ðGi Please sign and return confirming you have received this data. Thank you, .-K~~ Kaynell Zeman Exploration Aide Enclosures Hand Delivered Environmentally aware for the long run. {,' l UP1 Received by: Date: ~ I 2LJ 6)1j fi& ~~n û ~ ) Alaska ¡ .tn Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 20, 2001 Alaska Oil & Gas Conservation Commission Attn: Lisa Weepie 333 W. 7th Ave., Ste. 100 Anchorage,AJe 99501 LETTER OF TRANSMITTAL Via Certified Mail RE: Marathon Falls Creek #IRD CONFIDENTIAL DATA oD/-/55 Dear Lisa: Confidential digital well data for the above referenced well are enclosed A listing of the data is attached. Please review the enclosed data, sign and return one copy of this transmittal. Thank you, .1(~0g~~ Kaynell Zeman Exploration Aide Enclosures Certified Mail 7000 1530 0002 3067 1959 Received~.0. OrhfL'- / Date: ReCEIVED SEP 2 1 2001 A subsidiary of USX Corporation Alaska Oil & Gas Cons. Commisston Anchorage Environmentally aware for the long run ) Alaska Oil & Gas Conservatiol1 vommission September 20,2001 Page 2 Marathon Oil Company Falls Creek # 1 RD Kenai Peninsula, Alaska CONFIDENTIAL , , TNðNie(:·.::~;.<;:> :". ...... .... l£1 Combined AIT. PDS 89 Combined Ait-Sonic. PDS ~ Combined CALIPER.PDS IE) Combined DS!. PDS £) Combined NEUTRON-DENSITY. PDS ~ combined rft. pds S· FC_DIR.dat iIIII FC1.las ¡;¡¡;; fe: 1 rd field logs .Ias ~FC-1RD FINAL REPORT. doc ~ Fe 1 rd_final.las I·...· Felrd_mudlog.las ~: Fe 1 rd.J]roe:essed_dsi. dlis iIIII; Fe 1 rd.J]rocessed_dsl.las ;L. Fc 1 rd.J]rocessed_dsi. pds II!¡ FCltext.txt t,,;. Final Combined AIT. PDS :0:. F;na'=CCOTb".d ",-Soric. PD5 .t.: Flm!lLComblned CALIPER.PDS iL. Final_Combined DSI.PDS .L Final_Combined NEUTRON-DENSITY.PDS ~. Final_Combined rft.pds II! l proeessed_dsl. dlls 11III; proeessed_dsi.las ,¡¡,. proe:essed_dsl.pds ii: rft_029Itp.dlis rft_032Idp. dlis rFt_0:33Iup . dlis rFt_034Iup. dlls rft_035Itp. dlis rft_036Itp. dlls rft_037Itp. dlis rft_03Bltp. dlis rft_039Itp. dlis rFt_040lup .dlls rtt_u"t Iltp. dlls rft_042Itp.dlls rFt_043Iup. dlis rft_044Itp. dlis rft_D45Itp. dlls rFt_046Itp. dlls rft_04 7ltp. dlls rft_O"Bltp. dlls rft_D49Itp.dlis rft_050Iup. dlis II;: rft_051Iup.dlis rft_052Itp. dlls II rft_053Itp.dlis rft_054Itp. dlis . rft_055Itp.dlis In rft_056Itp.dlis II;: rft_057Itp.dlis II;: rft_05Bltp.dlis !!! rft_059Iup. dlis II rft_060Itp. dlis (!J rft_061Itp.dlis l::i rFt_062Itp. dlis II;: rft_063Iup. dlis · II;: rFt_OMltp. dlis · !!!! rFt_065Itp. dlis !!! rFt_066Itp.dlis @ rft_067Itp.dlis · (!J rft_06Bltp. dlis (!] WS_FTP.LOG B,726 KB PDSView Docum... 3,01 B KB PDSView Docum... 719 ICB PDSView Docum. .. 6, 139 ICB PDSVll!tw Docum... 2,239 1<8 PDSView Docum.. . 1,569 KB PDSView Docum.. . 791 KB DAT File 2, 125 KB LAS File 4,039 KB LAS File 338 KB Microsoft Word .,. 4,626 ICB LAS File 2, 125 KB LAS File 2,815 KB DLIS File 8, 154 KB LAS File 17,980 KB PDSVlew Docum. . . 51 KB Text Doe:ument B,726 ICB PDSView Docum. .. 3,018 KB PDSView Docum... 719 KB PDSView Docum... 6,139 K8 PDSVlew Docum... 2,239 KB PDSVlew Docum.. . 1,569 KB PDSVlew Doeum.. . 2,B15 KB DLIS File B, 154 KB LAS File 17,9BO KB PDSVil!tw Doeum.. . 500 K8 DLIS File 1,320 K8 DLIS File 453 KB DLIS File 336 KB DLIS File 551 KB DLIS File 663 KB DLIS File 570 KB DLIS File 539 KB DLIS File 537 K8 DLIS File 462 K8 DLIS File 1::1;':: I 1(.1::1 l)Ll~ !-lIe 537 KB DLIS File 394 KB DLIS File 363 KB DLIS File 6B5 K8 DLIS File 5Bl KB DLIS File 571 1<8 DLIS File 803 K8 DLIS File 72B KB DLIS File 264 K8 DLIS File 460 K8 DLIS File 628 KB DLIS File 605 IŒ DLIS File 612 IC8 DLIS File 661 KB DLIS File 516 KB DLIS File 4B9 K8 DLIS File 529 KB DLIS File 353 KB DLIS File 517 ICB DLIS File 867 ICB DLIS File 572 KB DLIS File 30B KB DLIS File 717 K8 DLIS File 660 K8 DLIS File 681 KB DLIS File 672 ICB DLIS File 875 IC8 DLIS File 1 K8 Text Document ) f B/17/2001 2:34 PM B/17/2001 2:56 PM B/17/2001 2:03 PM B/17/2001 2: 15 PM 8/17/2001 2:4e PM B/16/2001 3:20 AM 9/18/2001 1 :34 PM B/21/2001 9:22 AM B/15/2001 9: 14 AM 8/26/2001 10:45 AM 9/6/2001 12:52 PM B/21/2001 10:51 AM B/21/2001 12: 12 AM 8/21/2001 12: 11 AM B/21/2001 12:50 AM 8/27/2001 1: 53 PM B/17/2001 2:34 PM B/17/2001 2:56 PM 8/17/20012:03 PM B/17/2001 2: 15 PM 8/17/2001 2:48 PM B/16/2001 3:20 AM e/21/2001 12:12 AM 8/21/2001 12: 11 AM 8/21/2001 12:50 AM B/14/2001 2:"U PM 8/14/2001 3: 15 PM 8/14/2001 3:23 PM B/14/2001 3:28 PM 8/14/2001 3:40 PM B/14/2001 3:52 PM 8/15/2001 12:02 AM 8/15/2001 12: 11 AM 8/15/2001 12:20 AM 8/15/2001 12:27 AM 1::I/1~/C!uUl 1;¿:4' AM 8/15/2001 12:55 AM B/15/2001 1:05 AM B/15/2001 1:09 AM e/15/2001 1:21 AM 8/15/2001 1 :31 AM B/15/2001 1 :40 AM B/15/2001 1 :5B AM 8/15/2001 2: 11 AM B/15/2001 2: 13 AM B/15/2001 2: 18 AM 8/15/2001 2:2B AM 8/15/2001 2:3B AM B/15/2001 2:4B AM B/15/2001 3:00 AM B/15/2001 3:09 AM B/15/2001 3: lB AM 8/15/2001 3:27 AM B/15/2001 3:35 AM B/15/2001 3:42 AM B/15/2001 4:00 AM B/15/2001 ..: 10 AM B/15/2001 4:23 AM B/15/2001 4:36 AM B/15/2001 4:47 AM 8/15/2001 5:00 AM B/15/2001 5: 13 AM 8/15/2001 5:32 AM 9/12/2001 1:35 PM J .~iN Y~~\ IF ïê u U lí b ~~ mL~~~~ DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE., SUITE 303 JUNEAU, ALASKA 99801 http://www.state.ak.us/ded deh Ms. Lisa Pekich Senior Environmental Coordinator Phillips Alaska. Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONYKNO~ßQVERNOR ~~> //,. cS .L'- I ~~''- ~$,f. ,"/) <" : "'."1 c:lQ -1 "(' '/;/ ..P .> ."",. : Y'Q ;> <7$ . (" (:?,'() -1;?C',.?, 0017$ I o('~ 'C :9& 00-0, , '/.5'6,/;'" "-'l/ Telephone: (907) 465-5162 Fax: (907)465-5362 September 14, 2001 Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at nine exploration sites located on the North Slope, Southcentral, and Interior Alaska Dear Ms. Pekich: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for nine inactive reserve pit closure applications and requests for permanent closure approval. The closure applications provided the required information describing the history of the reserve pit(s), the present condition of the reserve pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits have been backfilled and there is no exposed drilling waste. ADEC coordinated review of the closure requests with the appropriate land manager(s). Public notice requesting comments on the closure requests was published August 3 and 4, 200 1 in the Anchorage Daily News and posted on the State Web Site August 2, 2001.. No public comments were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure re;quirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to Phillips Alaska Inc. for the inactive reserve pits at the following nine exploration sites: Well Name API Number \~,.....OS ~ Beluga River Unit 212-25 I G 50-283-10025-00 Birch Hill Unit 22-25 ~~~~ 50-133-10029-00 \Cas -CJO \ \fed _ CYs <J Swan Lake Unit # 2 9~ ~ 50-133-10021-00 ~~t)'-\J I J,()\.\SSFalls Creek Unit # 1 (13-06) (,..~.s.50-133-1 0005-00 ~ 5 -(J ~ ~ Rainbow Federal # 1 ~~ þ." 50-099-10004-00 ¡ <CCo -t)~ \ Rainbow Federal # 2 \>~ P:>... 50-099-10005-00 10 .(Jè)$ , '~-t)~a Kaiiakh #212 RD ~ ~ ~ 50-033-10002-00/0 I .<6~ -Od~ KRU West Sak SWPT #1 <=:f.J":>? 50-029-20915-00 \'\L\.-OCY, West Sak River State # 2 ~'Ì~50-029-20134-00 MTRS Sec. 25 13N,IOW,SM Sec. 25 09N, 09W,SM Sec. 3 07N, 006W,SM Sec. 6 OIN, 12W,SM Sec. 31 08N, 05W,CR Sec. I 08N, 05W,CR Sec. 28 20S, 014E,CR Sec. 11 1IN,lOE,UM Sec.221IN,IOE,UM Landowner ADNRJADF&G c..~\)'f<:)~1 ~~~\ ?K~ USFWS U f'-G<:"~ \ USFWS S\\"L\o.~ \ ~\«(() l~~,-~ Pri vate Property c..'t't.~~ J Ä~t:J,<~\ ~~ BLM r~Sl<-G (t(~((;:) BLM ~~'-.CJ I ç;>~,-~ DNR Q\c. \"~\'t~ I ~lta { ~ \>'-0 DNR ~R<-a ( \> ~'-o DNR ~Qc.s::J{ ?~~ .;j printed on recycled :Japer ) ) Phillips Alaska, Inc. Ms. Lisa L. Pekich September 14,2001 Page 2 Terms and Conditions This final closure approval is subject to the following terms and conditions: 1) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the ownerloperator and the appropriate land owner/manager. Any person who disagrees with any portion of this decision may request an adjudicatory hearing in accordance with 18 AAC 15.200-310. The request should be mailed to the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and granted, this decision remains in full effect during the adjudicatory process. Sincerely, ~~,~l Heather T. Stockard Solid Waste Program Manager Heather Stockard@envircon.state.ak.us cc: Harry Bader, ADNR, 3700 Airport Way, Fairbanks, AK 99709-4699 Deborah Heebner, ADNR, 550 W 7th Ave. Suite 900C, Anchorage, AK 99501-3577 ~1P._t~e:¡~;rf.~~.&r~~~rØiQ\1f.~~~» William Friar, BP Exploration, P.O. Box 196612, Anchorage, AK 99519-6612 Don McKay, ADF&G, 333 Raspberry Rd., Anchorage, AK 99502 Harold Pederson, 925 R Street, Anchorage, AK 99501 BLM, Ramone McCoy, BLM District Manager, Box 147, Glennallen, AK 99588 Claire Caldes, USFWS, Box 2139, Soldotna, AK 99669-2139 Charles Underwood, Marathon Oil Company, P.O. Box 196168, Anchorage, AK 99519-6168 ) Alaska Ré ) Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 29,2001 Alaska Oil & Gas Conservation Commission Attn: Lisa Weepie 333 W. ih Ave., Ste. 100 Anchorage, AK 9950 I LETTER OF TRANSMITTAL Via Certified Mail RE: Marathon Falls Creek #IRD CONFIDENTIAL DATA Dear Lisa: The following CONFIDENTIAL digital data are enclosed for the above referenced well: Final W ell ~~ports - Paper Copy ,/ . . \ S S Standard DIgItal Mudlog 2"=100' MD - Paper Copy V ~¡ Standard Digital Mudlog 2"=100' MD - Vellum Cop~ Standard Digital Mudlog 2"=100' TVD - Paper Copy~, Drilling Dynamics Log 2"=100' Jy1D - Paper Copy ;:../ Digital LAS Data - CD Rom /' Please review the enclosed data, sign and return one copy of this transmittal. Thank you, 4(C;µrJO ~ Kaynell Zeman Exploration Aide Enclosures Certified Mail: 7000 1530 0002 3067 1843 x } ~ ,- Recei ved·by: '- ~,1,ø-- Date: Û-t'Ô ZP¡lJ I A subsidiary of USX Corporation Environmentally aware for the long run Alaska Re, " Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 CONFIDENTIAL. August 24, 2001 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon Falls Creek #l.eÙ CONFIDENTIAL LETTER OF TRANSMITTAL Via Certified Mail Dear Mr. Oakland: ~ol"l55 D J-\LJG 28 ~~ .J,:¡ .¡ ) ... i.." Ü \ R'_,....,;_ ""... "" ^_... )'\"":i~,.,,.. ('I1"I"'mi!'''~'''''' The following CONFIDENTIAL digital data are enclosed for the above referenced well: ........ ....... ,".. ..... ........................ ............. ...... .......", no·......... ........ ............. ........... ... .................... [ ~" ---.'. T'- ..... -..-.. -.. "....... .,". .... -.-.·S.iZ.. ;r. ·.·.,T. .. Y". ..p'.~,". -"....-...-....,.....~-' ......,..-.,...-".,...,".....,.,...., -. '" .,", ·...r·-.,M,....,.·.~.o",·,d,.·,·, i-,F,..i.~,.·-".d",.·,·,·,·.·..,....'.....,..,. ~ .."....-......." ........ '" [~~~;;~~b~~;~~.,~D~::~:--- t ." . : ~ Final_Combined Ait-Sanic,PDS , ~ Final_Combined CALIPER,PDS , IE) Final_Combined DS!, PDS ! li'1 Final Combined NEUTRON-DENSITV,PD5 SJ 726 KB 3J01B KB 719 KB 6}. 139 KB 2.239 KB PDSView Document PDSView Document PDSVielt'll Document PDSView Document PDSView Document 8/17/2001 10:34 PM 8/17/2001 10:56 PM B/17/2001 10:03 PM 8/17/2001 10: 15 PM 8117/2001 10:4B PM Please review the enclosed data, sign and return one copy of this transmittal. ." 'I," Thank you, "VÚe" nfJO(} 11( JWY-Y'Õ1'~~ Kaynell Zeman Exploration Aide Enclosures Certified Mail: 7000 153000023067 1805 ~v;) "" I t1 ) Received~ fJ-.JL-~ Date: <?, / a.X / () I A subsidiary of USX Corporation Environmentally aware for the long run .. ,I'I . ") TO: State of Alaska Alaska Oil and Gas Conservation Commission \M~ "- Julie Heusser, ð"~ - ~O DATE: August 1,2001 Commissioner 1>\ ð Tom Maunder, .~_II -,~ Petroleum Engineer 1Ji;P!;cP \ ~~~~ ,LQu<Grimaldi, SUBJECT: Petroleum Inspector Leak Off test Falls Creek #1 RD 201-155 Falls Creek Unit MEMORANDUM THRU: FROM: Wednesday. Aug\lst 1. 2000; I traveled to Marathon's Falls Creek #1 RD well to ,. ' witness the Leak-Off test on the sidetrack. The Leak-Off test produced an Equivalent Mud Weight of 15.5 ppg, the shut-in pressure on, the tail ,end ,of the test kept dropping at a rate of approximately 8 psi per minute. I observed samples of cement and formation returned when the casing window had been drilled. Roland Lawson (Marathon rep.) made good preparations for this test. SUMMARY: I witnessed the Leak-Off test on Falls Creek #1 RD, a 15.5 E.M.W, was observed. Attachments: LOT Falls Creek #1RD 8-1-01 lG ~ Pete Berga (Marathon Drilling Supt.) NON-CONFIDENTIAL LOT Falls Creek #1 RD 8-1-01 LG.doc Wen Name .FaUa Creek #1 RD Pel'lY\lt to Drill # 201·155 121S18/1/01 ODerator Marathon Field/Unit fall.Creek ComDanv ReDI'Hentatlve ,~owland I awaon BIa .Glacler Drllllna #1 A.O.G.C.C. In.Deetor Lou Grimaldi LEAK OFF DATA 8.701 ~ 0.452 1Q1.Q mQ 1m .1jlQ~ 1015 COMMENTS Anticipated maxBHP at T.D. for u.pcoming casing section T,V.D. at Total Depth M.W. needed to balance wells max Dressure Mud Weight called for in program AOGCC Confidential -~ Mud Weight in hole (P.P.G.)I $.G. of Mud in hole Gradient of Mud in hole Surface pressure at break Surface pressure taken to Surface oressure bled to (10 seconds) Surface pressure bled to (1 minute). Surface oressure (Stabilized) Cover Sheet Page 1 LEAK OFF TEST Surface Hole T.D. N/A Drill Out MO ~ Drill Out TVD 304Q. Hydrostatic Head of MUd at T.D. ~ a.H.p. at T.D. (with Leak Off pressure applied) ~ EQuivalent Mud Gr,dient ~ EQuivalent Mud Specific G¡avllY ~ ~ulvalent Mud Welaht at Break (P.P.GJ 15.4fi Is this a repeat test HQ If Yes what was last tests EMW ? Volume of fluid pumped during L.O.T. ~ Volume of fluid returned after bleed-off 1JM , Updated by L.G. 8/4/98 æz ~ MQ U 010801-LOT Falls Creek #1-LG.xls Page 1 of 3 8/8/01 AOGCC Confidential _ _ ~!'f8I8 Casing .test Leak Off test 0.00 50 0.25 100 0.50140 - 0.75" -270' '-1.00 465 1.25 - . 660 - -1.50 855 . "1.76 - u ------ - 1-Õ3Ò "loo 1185 . 2.25 1290 , 2.5Efo 1290 1 :60' " 2~ÓÓ ~OO 4.00 ~~-. "5:00 -"S.OO' 7:00 8.00 . - 9.00 ---·-10.00 n.06 '. .----. ---._-------------_._~-- - - - .------ ------------- ----. --~ , ~aXgqlJJv Mud We[gt)~.._~_. . Present Mud Weight- I Difference- TVO of shoe- Mix Surfäœ 'pressure- Updated by L.G. 8/4/98 -'" Leak Off Test . Delta PSI Shut-In 0- 50 '40· 130 195 195 195 . , '175 -- 165 105 o ·1290 -- '0 _n -~- .. ó. . o '0 o o o Ó ---- - -- -----.. ----- - .~~~ 15.5 . 8.7 6.78' 3040 1072 PSI 1173 1120 --1085 . '1070 "10ëó -10'60 1043 1039 1029 - u 1024 161e-' 1015 - --------- - Max L.O.V. o o o o o o o o m---o -º-. o o o o o o -º- L.a.T. #1 (Data) Page 1 ~: L~ .-- ._-~~~~~~~~~~~~--~,~=.~-,_,_"~_'_-,~--.~,--...~~ 1300 f-~~~~---' _~~~~~~~~~~~_~_"~__--~",_--_--=,u.._ - ,- 1260 }-- uu. -.-~=~~~~._-. --- -",~~~~~~~~--'~.~._'..~~-~.---~~-~-._'..."- 1200 ~~~-- --=-- -~ _n. --,- _u~~~~~-~______~~-.______~'~..~~-~ 1150 ;-" -..~- - -~_. --=. -- -~. '~~.~~-~'-~-~'~--'--', ~'~------'~'-'~---~-"'- 1100 i'-'~~~~~~' - .~~.~~-. . ""~~~~~'.~-~~-.-~.,~- --.., --,~_._- ~.-'. 1050 ~~,~~--_.~= -~ - -.~~~ '--~~~~--~~----- ; 1: L-=~~~~.-- ~::~~=:: . __ .~ ~-: -:: : :-._-~~ ::. .. ~~~~,~~ "u.:~~~.~.'c_~-==:~,~~:==.:~~:'~~~~:~=~': . 900 :______ .n_. .u.~. ~~~. __n~~~~~~,~~_~._.,.~~-~.,-_.".__,-.. .',.__' : F: > =-~ .. n:i;~~ .=~- ~. .~:~---~-~;~:-;:~:--~=j_~:~; r 660 ~~~-~=~~~~ ~~--~'~~-~~~-~~~~.~--~-~.~.-.'~~'--~~~'-'-'-~~.-.'-'~~~-~.-~'~-~'-'-"-"--'-'-~---.'-"--'--'.-.-~'. -~~'.- · eoo ---- -=-==--o:...-~-=~_ -'- ..o----=-=---=-~~..=_="-._~_'_-_-_'__o_.___,_"._'_-__,___._;_,.__-.'_-~~___._._- _'_'-_·.-_T~_.·_ -.-..-.. ::::':'·'Ci'ìíng':'i.'f-'~· : 660 -.~~~ -. '~=~~~~~~~.~~-.'~~-~~,'-"...__.-.'-'-~-_.'----...~'-.'. ..'.- -L..k Off t..t II 500 --~.- -~~----"-~~-~~~~-~~~---~-.----._'~".'--~---'-- -Shut.ln r 450 ~-- ~~-~ --- .n~~~~~~~_~~_~~_~~"=.'.~'-~~_'-~.. -'~~---' --.~,-,,-.. -'- ..==,~~~'.~~:_. . 400 i-'~'-~'~~~" ~=.'-'~'~~~.~~~~~~._=~'~-~~~'-'-'~-.-.--~'~~--.-~~'~'--.-'-~-'-'-'~,-,-,--'-'-',',-.-,_-'.~'-,-.".'-,---'--. 350 ;._-- - '-' ~-"-~~--~~~~~~~~~~~'~~---'.'~---'-.'.------'-~~-- 300 :..u~ ,____n __n~-~~_~,~~~'~=~~~_:_-__.~.~._~'~_'__._·.__--..___ --__.... 250 ~~=.._._. .-~~~~~~~~~~-~.=.~~~"~....--~----~~------..~.-.,..------ 200 ,-._--=--~~-== ~ ~===-=-~-=-,"---,,"_~-------,-_.~_~_..,..-,-~~---,---,_r-....,...____~____"",__--,_'__ 150 i-~-. ~..---- ,," -'--~~~~~~~~~=~~~.~~-.~~-~~~--...~.---..------- ,--~ 100 r~~ -~~,~~~-'-'~'~~~-~-~~~~--'-'~"~~'~~~--.~.~.~-"'.-.-~'-."..,.~..~.--.~._..,.,-,--',-'._'" 50; -- ~~-- -~~-~-~~-~-~--~-~-~--,~~--<-_._- -------,- --- o ,~__~._.~..r'.__~.~_..__,._._._~.L._ "-, ~~~~~~~~~~~~~~~~~~~~~~ Strok../Mlnute. 010801-LOT Falls Creek *1-LG.xls Page 2 of 3 8/8/01 1400 - 1300 - 1200 --- ---- ----~- A 1100 -- 1000 -- C . a . 900 I n BOO _ g P 700-- r e s . u r e eoo- 500- 400-< 300 --- . 200 ~-~~-- - ~- 100 o 0,00 . Updated by L.G. 8/4/98 ~ 0.50 ~ . . - - -. --- --------- fa 1.00 A ~ ~ 1.50 -------.--.-------- - -~~~~~~~-~~~- ~ ---.----~ ~B ~_....~---~- --.; "'- . c- ___~~~-D ----- ---- -X-X-X_X_>e--; 1\ x-~-)(_J, \ --- - ---- --- - '--IT---- o 1 2 3 4 5 6 7 8 9 10 11 ----~ SHUT-IN TIME IN MINUTES (for -x-) -_._---~---~...".-- ~ ---- ------ ----~ ---- -~~~----- ~ ------ -- A - Leak Off Point B - Stop Pump & Close Valve ~ C - 10 Second Shut-in Pressure D - End Of Test ~-- -~ ......~ -¡-- ---,-----.-.---- . 2.00 2.5/: 10 2,00 4.00 6.00 8,00 10,00 BarrelsIMinutes ~--~_.. 010801-LOT Falls Creek #1-LG.xls ~_. _.~._~~~~..----.-.. -<>- Casing test -6- Leak Off test -x- Shut-in -o-MaxL.O.V. "----- - -- 8/8/01 2ö1-- 155 ~~!Æ~E ~ ) ! fÆ~!Æ~~~!Æ ì J ~ TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 1, 2001 Mr. Peter K. Berga, Drilling Superintendent Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-5311 Dear Mr. Berga: On the pennit to drill application for the Falls Creek # 1 RD well, I assigned an incorrect API number. Please change the API number in your records for this well to: 50-133-10005-01 I apologize for any inconvenience or confusion this may have caused. If you have' any questions, please call me at (907) 793-1224. Sincerely, ~~ Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission cc: Reading File Well File ~~~~E ~ I' F ~~~~~~] TONY KNOWLESJ GOVERNOR ~ AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 219-1433 FAX (907) 216-7542 P.K. Berga Drilling Superintendent . Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 Re: Falls Creek Unit #lrd Marathon Oil Company Pennit No: 201-155 Sur Loc: 1898' FSL & 2885' FEL, Sec. 6, TIN, R12W Btmhole Loc. 1898' FSL & 4913' FEL Sec. 6, TIN, R12W Dear Mr. Berga: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Enclosed is the approved application for pennit to drill the above referenced well. The pennit is approved subject to full compliance with 20 AAC 25.055. However, prior to perforating and testing or producing this well, Marathon must make application to the Commission for a detennination of whether or not a spacing exception is required. Marathon will assume the liability of any protest to the spacing exception that may occur. Annular disposal has not been requested as part of the Pennit to Drill application Falls Creek Unit #lrd. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~M~~~ Julie M. Heusser Commissioner BY ORDER OF-æ.-HE COMMISSION DATED this b1 day of July, 2001 cc: Department ofFish & Game, Habitat Section wlo encl. IÆ¡:art:IœIlt of Envirornæntal Conservation wlo encl. 1a. Type of Work DrillD Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1898' FSL & 2885' FEL See 6, T1 N, R12Vv ) STATE OF ALASKA ) 9'<m"Id,g~te,;"g~"44-10\AOOCCPTD.XLW;',\ ALASKA OIL AND GAS CONSERVATION COMr\tIlSSION 1:J'1 PERMIT TO DRILL 210 AAC 25.005 Re-Drill[8] DeepenD Type of well. Exploratory[] Stratigraphic TesD ServiceD Development Ga{8J Single ZonG 5. Datum Elevation (DF or KB) 10. Field and Pool 282' Falls CreeklTyonek 1b. Development OiD Multiple Zone[8J 13. Distance to Nearest Well 6. Property Designation /ÌDL- Cx:>5-Cl¿).AÞ 7. Unit or Property Name Falls Creek Unit 8. Well Number Falls Creek #1 rd 9. Approximate Spud Date 7/27/2001 14. Number of Acres in Property 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200000 15. Proposed Depth (MD and TVD) At top of Productive Interval 1898' FSL & 4635' FEL See 6, T1 N, R12Vv At Total Depth 1898' FSL & 4913' FEL See 6, T1 N, R12Vv 12. Distance to Nearest Property Une(unit boundary 1325 feet 16. To be Completed for Deviated Well: Kickoff Depth 3150 feet Maximum Hole Angle 18. Casing Program Size Hole Casing Weight 26" 20" 97 18 5/8" 13.375" 54.5 12 1/4" 95/8" 40 6 3/4" 4 1/2" 12.6 4000 feet feet 8874'md/8306' tvd 630 44 0 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2» Maximum Surface ~ ar;\) pslg at Total Depth (TVD) Setting Depth ~1t1t Top Bottom 8306' Specifications Grade Coupling ? ? J-55 STC N-80 LTC L-80 LTC Length MD TVD MD TVD 248' 0' 0' 248' 248' 2468' 0' 0' 2468' 2439' 3150' 0' 0' 3150' 3094' 8874' 0' 0' 8874' 8306' Quantity of Cement (including stage data) In Place, wi 480 sacks In Place wi 1660 sacks In Place, wi 1884 sacks 900 sx Falls Creek Unit well Falls Creek #1 will be plugged back according to AOGCC regulations to 3150' MD and sidetracked. Falls Creek #1st will be directionally drilled to an estimated total depth of 8874' MD/8306' TVD from the existing Falls Creek Unit location.The production interval will be cased with 4 1/2" casing and cemented. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. Note: MASP is during drilling. During production it is 2932 psi. 20. Attachments Filing Fee[8J Property Pla(8] BOP Sketch[8] Drilling Fluid prograrrG Time vs Depth PloD Refraction AnalysiU 21. I hereby certify that the fo~egOin is true and co. rrect to the best of my knowledge ~~ ~ ~ Phone: 564-6319 Signed P. K. Berga ¿~ ¡r {~~ Title Drilling Superintendent Commission Use Only Permit Number API Number Approval Date ~.., I See Cover Letter .20 j-. / Sç 50- / '33 - j {){;{)5-C:¡ 7 ,/0 L For Other Requirements Conditions of Approval Samples Required DYes [R] No ' Mud Log Required DYes ~E eEl VE 0 Hydrogen Sulfide Measures DYes ~ No Directional Survey Required ~Yes D No Required Working Pressure for BOPE D2M -ø D5M D10M D15M Other: 'OR\G\NAl S\GNED BY J. M. Heusser Approved by Form 10-401 Rev. 12-1-85 Diverter SketcO Seabed RepoG Drilling Prograrr[8] 20 AAC 25.050 RequirementO Date:~0 / JUL 2 7 2001 Commissioner by orde~fska Oil & Gas Cons. Commission the Commission An<a~fgge Submit in Triplicate ORIGINAL ) ') :1 Marathon Oil Company Alaska Region Prepared By: P. K. Berga Approved By: Date: 07/26/01 Dri1ling progræm Well: Falls Creek #1 RD AFE: 1506101 Area: Falls Creek Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No. 1 Geologic Program Depth Target Locations FSL FEL Block MD TVD Surface 1898' 2885' Sec. 6, T1N, R12W, S.M. 21' 21'OKB ( 15 ' OKB) ( 15 ' OKB ) Tyonek T-1 1.898 ' 4635' Sec. 6, T1N, R12W, S.M. 5538' 5006' Tyonek T-3 1898' 4913' Sec. 6, T1N, R12W, S.M. 7574' 7006' Bottom Hole 1898' 4913' Sec. 6, T1N, R12W, S.M. 8874' 8306' OKB=Original Kelly Bushing RKB Elevation: RKB to MSL=282, (original hole/well 276' ) GL-MSL=261, Tolerance Total Depth: TVD 8306' MD 8874' Max. Angle 44 Course 270 Abnormal Pressures: N/A Subnormal Pressures:N/A Coring and DST's: N/A Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection. 30' samples to TD Logging Program: Contractor To be determined Surface Production LWD NA NA Wireline Logs GR/AIT/DSI/NGT FC #lrd Drilling Program Page 1 of 8 ) ) Drilling Program Summary Production: The existing wellbore will have been plugged back to <= 3150' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at ±3150' MD. Test plug and casing to 2500 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees right of highside for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (13.5 PPG anticipated). Drill a 6 3/4" hole to 8874' MD/ 8306' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 4 1/2" production casing and cement per the attached program. Proceed with completion program. Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type ( in) (psi) (psi) (K lbs) (MD) 9 5/8" 0' 3150' 40.0 N-80 BTC 12 1/4" 5750 3090 916 4 1/2" 0' 8874' 12.6 L-80 BTC 6 3/4" 7780 6350 267 Note: The 9-5/8" casing is already installed. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) ( pp f ) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8" 40 N-80 3094' 13.5 9.0 1043 2.6 3.6 NA 4 1/2" 12.6 L-80 8306' 9.0 1490 2.13 1. 43 1. 83 FC #1rd Drilling Program Page 2 of 8 ') Directional Progr~ Directional Co: Baker Hughes Inteq KOP: 3150 Direction: 268 Drop Depth: 4400' MDI 4058' TVD Gyro Survey Required: at TD ) Gyro Co: To be determined Build Rate: 5.0 To: 44 deg @ 3550' TVD Drop Rate: 1. 75 ave. To: 0 deg @ 6437' TVD Magnetic Multishots Required: Use MWD surveys below KOP past interference. General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 9 5/8" Intermediate Casing @ 3094' TVD MASP [(PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)] MAS P [ (9 . 0 * O. 0 52 * 83 0 6 ) - (0. 3 * O. 052 * 9. 0 * 83 0 6 ) - (0. 7 * O. 1 * 83 0 6) ] MASP 2472 psi 4 1/2" production MASP MASP MASP Casing @ 8306' TVD* [PP * 0.052 * TVDf - [9.0 * 0.052 * 8306' 2932 psi FC #lrd Drilling Program (GG * TVDf)] - (0.1 * 8306')] Page 3 of 8 Cementing Program Production Casing Size: 4 1/2" Lead Slurry: Top of Cement: Specifications: Compress Strgth: Tail Slurry: Top of Cement: Specifications: Compress Strgth: Total Volume: ) ) Contractor: BJ Services Setting Depth: 8874' MD/ 8306' TVD Annular Volume to 2650' with 6 3/4" gauge hole: 932 ft3 Density:~ ppg, Yield: 2.08 ft3/sx, Sx: 300 sx, cf: 624 ft3 2650'MD/ 2612' TVD Class G + additives Mixed w/ fresh water 500 psi in 10 2000 psi in 16 hrs hrs, Density: ~ ppg, Yield: 1.15 ft3/sx, Sx: 600 sx, cf: 690 ft3 5508'MD/ 5006' TVD Class G + additives Mixed w/ fresh water 500 psi in 6 hrs, 3600 psi in 24 hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions. 1314 ft3, *50% Open Hole Excess, wac Time: 6 hrs FC #lrd Drilling Program Page 4 of 8 ) ) Diverter and BOP progræm The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Casing Test Size MASP Test BOPS Low/High ( in) (psi) (ps i) Size & Rating (psi) 2472 1500 ( 1) 13-5/8" 5M Annular 250/3000 / 9 5/8" (9.2 ( 1) 13-5/8" 5M Blind ram 250/3000 ../ ppg (2) 13-5/8" 5M Pipe ram 250/3000 ./ ../ mud) 2500 (1) 13-5/8" 5M Annular 250/3000 / 4 1/2" 2932 (10.0 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) Intermediate Production Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 9 5/81. Intermediate Casing at 3094' TVD CTPMASP = 2472 psi CTPBurst = 5750 * 0.7 - «9.0-8.3) * 0.052 * 3094) Test to 2500 psi 3912 psi 4 1/2" Production Casing at 4050' TVD CTPMASP = 2932 psi Test to 3000 psi CTPBurst = 7780 * 0.7 - «9.0-8.3) * 0.052 * 8306) 5144 psi FC #1rd Drilling Program Page 5 of 8 ) ) Mud Program Contractor: Ml Drilling Interval (TVD) From 3094 ' Fluids Mud Weight (ppg) 9.0 - 9.5 Water Loss <8 Mud Type Flo Pro/KCI To 8006' Wellhead Program Manufacturer Model Tubing Head Tubing Hanger Vetco Annular Flow 11" 3M x 9 5/8" 5M 9 5/8" x 4-1/2 Mandrel Tubing hanger Detailed Drilling Procedure Fo~tion Leakoff Test Inter.mediate casing shoe will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the lADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Bi t Program The following guidelines are recommended for use on this well. Interval (MD) 3150' - 8874' Bit Size ( in) 6 3/4" Bit Model Smith-To be determined lADC Code WOB (k lbs) RPM FC #lrd Drilling Program Page 6 of 8 ) ) Drill String Item 3 %" HWDP,3 %" IF Ppf 24.4 Makeup Torque 12000-13200 ft.-lbs. Max Pull -Premium 248,000 Ibs 4", 8-135, HT 38 15.53 13,500-19,800 ft.-lbs. 29,000 ft.-lbs. 403,500 Ibs. 5" HWDP, 4%" IF 49.3/53.6 543,000 Ibs. Hydraulics Program Rig mud pumps available are shown below. Install 4 1/2 " liners in all mud pumps. Make Oilwell Liner ID Stroke Max Press Gal/Stroke Max Rate Model ( in) ( in) (97% eff) ( spm) A 600 PT 4 %" 8" 3207 1. 6005 135 A 600 PT 5.0 8" 2597 1. 9788 135 A 600 PT 5 %" 8" 2147 2.3959 135 Oilwell Oilwell Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) ( in) ( gpm) (ps i ) ( fpm) (ppg) (32"s) 8874' 6 3/4" +/-265 2200 - 175 9.5 14,14,14 2800 Remarks Motor Drilling Note: 4 1/2" liners are recommended. FC #lrd Drilling Program Page 7 of 8 ) ) OPERATIONAL PROCEDURE 1. Abandon existing perforations according to program filed with AOGCC. RIH and set CIBP at +/- 3150' md. Test plug and casing to 2500 psi.~ 2. 3 . MU and RIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside casing exit. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 13.5 ppg anticipated}. 4. Drill a 6 3/4" hole to 8874' MD/ 8306' TVDper the attached directional program. Backream each stand. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole: 5. At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH. Run logs as per geology requirements. Make wiper trip. POOH laying down drill pipe. Pull wear bushing. 6. Install and test casing rams. 7. Locate pump in sub and safety valve. Function safety valve and place on rig floor. Record function test in IADC book. RU and run 4 1/2" casing. 8. Cement casing as per the attached cementing program. Displace cement with KCL. 9. Test hanger. Set BPV. N/D BOPE and N/U and test tree. FC #lrd Drilling Program Page 8 of 8 ) Created by ,utherlo Detll plotted: 2J-Jul-2001 Plot Refllrence is FC #1 Version #1. Coordinates ore in feet reference Slot fJlA. True Vertical Depths ore reference RKB 282', 1\. ') Well : FC II 1 MARATHON Oil Company --- Boker Hllih", INTEO --- structure: Falls Creek Unit #1 Lacation : Kenai Peninsula, Alaska 800 - ŒJ 1200 - 1 600 - 2000 - 2400 - 2800 - 3200- ........... 3600 - - Q) Q) "+- 4000 - '-" ..t: - c.. 4400 - Q) Q 0 4600 - 0 - "- Q) > 5200 - Q) ::J "- 5600 - l- I V 6000 - 6400 - 6600 - 7200 - 7600 - 8000 - 8400 - 8600 400 o Field : Falls Creek Field 2200 2000 <- West (feet) 1800 1200 800 1600 1400 1000 600 400 200 o 200 - 200 / - 0 U) --- 0 -- s:::: " - 1-0 - 200 :r ........... ~ ..... CD - 400 CD - ............ I - 600 V - 800 End of Drop Target 2 ---- WELL PROFILE DATA ---- ----- Pl>lnt ----- .., Ino Dlr 'ND North !:øIt V. So<:t DoV I co KOP 31SO.oo 16.63 28&.34 .10113.511 -187.57 -.rnJ.05 .rnJ .De 0.00 Con~nu. BuMd 3170.00 19.o.! 288.J4. 3 I 12.112 -187.15 -.J78.18 .J78.18 '2.00 End 01 _/Tum .-.50 40VJ 279.~ J55CJ..J5 -141.24 -e¿c..U IlU,.U s.oo End 01 Hold ..,.,Z.GO ....., 279.~ .cœJ.18 -ð.UJ -1131.22 1131.22 Q.oo TŒgOt ~.IZ 22.00 27Q.00 _6.00 0.00 - I 150.00 1750.00 2.00 End 01 Drop ~.711 0.00 27Q.00 6oOJ6..BII 0.00 -202a. 14 2CJ2II.14 1.50 End 01 Hold ~7J.iCJ 0.00 210.00 1UJ6.CO 0.00 -202a.14 2028.14 0.00 T.o. ð: Eod 01 Hold 1187J.iCJ 0.00 210.00 ðJ06.00 0.00 -202a. 14 2CJ2II.14 0.00 44.43 End of Hold 44.28 40..33 36.39 32.46 DLS: 2.00 deg per 100 ft 30.50 28.55 26.60 24.66 22.73 21.00 19.50 18.00 16.50 15.00 DLS: 1.50 deg per 100 ft 13.50 12.00 10.50 9.00 7.50 6.00 4.50 3.00 1.50 0.00 KOP 20.46 25.30 DLS: 5.00 deg per 100 ft 30.19 35.11 44.43 End of Build/Turn :\ " , "- "- "- " -.. \, " .... \ ... "- \ ì '\ \ ~ , \ ~ ~ ¡ . T I I I I I r I I I I I I I I J. 400 800 1200 1600 T.O. 2000 2400 2800 Vertical Section (feet) -> Azimuth 270.00 wifh reference 0.00 N, 0.00 E from Slot #1 A ') ) " MARATHON Oil Company Falls Creek Unit #1 FC #1 Slot #IA Falls Creek Field Kenai Peninsula. Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License FC #1 Version #1 prop4805 Date printed Date created Last revised 20-Jul-2001 20-Jul-2001 20-Jul-2001 Field is centred on 242770.254.0.000.999.00000.N Structure is centred on 242770.254.2267493.144.999.00000.N Slot location is n60 11 38.486.wI51 24 54.492 Slot Grid coordinates are N 2265600.022. E 242477.659 Slot local coordinates are 1899.00 S 252.00 W Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ~"o~ ~ ,~u.. ~ \ 0 \~c.., c...C). ).ç;Ð 0 ~..::>~ ~ ~'o:. ~ ~~~ ) ) , MARATHON Oil Company PROPOSAL LISTING Page 1 Falls Creek Unit #l,FC #1 Your ref : FC #1 Version #1 Falls Creek Field,Kenai Peninsula. Alaska Last revised: 20-Jul-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 3150.00 16.63 268.34 3093.59 167.57 S 370.06 W 0.00 370.06 3170.00 19.03 268.34 3112.62 167.75 S 376.18 W 12.00 376.18 3200.00 20 .46 269.61 3140.86 167.93 S 386.31 W 5.00 386.31 3300.00 25.30 272.85 3232.97 166.98 S 425.16 W 5.00 425.16 3400.00 30.19 275.10 3321. 44 163.68 S 471. 58 W 5.00 471. 58 3500.00 35.11 276.78 3405.61 158.04 S 525.22 W 5.00 525.22 3600.00 40.05 278.09 3484.84 150.12 S 585.66 W 5.00 585.66 3688.50 44 .43 279.04 3550.35 141. 24 S 644.47 W 5.00 644 .4 7 4000.00 44.43 279.04 3772.80 106.99 S 859.81 W 0.00 859.81 4392.60 44.43 279.04 4053.18 63.83 S 1131. 22 W 0,00 1131. 22 4400.00 44.28 279.00 4058.47 63.02 S 1136.33 W 2.00 1136 . 33 4500.00 42.30 278.55 4131. 25 52.55 S 1204.09 W 2.00 1204.09 4600.00 40.33 278.07 4206.36 43,00 S 1269.42 W 2.00 1269.42 4700.00 38.36 277 .54 4283.69 34.38 S 1332.22 W 2.00 1332.22 4800.00 36.39 276.97 4363.15 26.71 S 1392.43 W 2.00 1392.43 4900.00 34.42 276.34 4444.66 19.99 S 1449.98 W 2.00 1449.98 5000.00 32.46 275.64 4528.10 14.23 S 1504.78 W 2.00 1504.78 5100.00 30.50 274.86 4613.38 9.44 S 1556.78 W 2.00 1556.78 5200.00 28.55 273.99 4700.39 5.63 S 1605.90 W 2.00 1605.90 5300.00 26.60 273.00 4789.03 2.79 S 1652.10 W 2.00 1652.10 5400.00 24.66 271. 87 4879.18 0.94 S 1695.32 W 2.00 1695.32 5500.00 22.73 270.56 4970.75 0.07 S 1735.49 W 2.00 1735.49 5538.12 22.00 270.00 5006.00 0.00 N 1750.00 W 2.00 1750.00 5604. 79 21.00 270.00 5068.03 0.00 N 1774.43 W 1. 50 1774.43 5704.79 19.50 270.00 5161.84 0.00 N 1809.04 W 1.50 1809.04 5804 . 79 18.00 270.00 5256.53 0.00 N 1841.19 W 1.50 1841.19 5904 . 79 16.50 270.00 5352.03 0.00 S 1870.84 W 1.50 1870.84 6004.79 15.00 270.00 5448.28 0.00 S 1897.98 W 1.50 1897.98 6104. 79 13.50 270.00 5545.20 0.00 S 1922.60 W 1.50 1922.60 6204.79 12.00 270.00 5642.73 0.00 S 1944.67 W 1.50 1944.67 6304.79 10.50 270.00 5740.80 0.00 S 1964.18 W 1.50 1964.18 6404.79 9.00 270.00 5839.36 0.00 S 1981.11 W 1.50 1981.11 6504. 79 7.50 270.00 5938.32 0.00 S 1995.46 W 1.50 1995.46 6604. 79 6.00 270.00 6037.62 0.00 S 2007.21 W 1.50 2007.21 6704.79 4.50 270.00 6137.20 0.00 S 2016.36 W 1.50 2016.36 6804 . 79 3.00 270.00 6236.98 0.00 S 2022.90 W 1.50 2022.90 6904. 79 1.50 270.00 6336.90 0.00 S 2026.83 W 1.50 2026.83 7004.79 0.00 270.00 6436.89 0.00 S 2028.14 W 1.50 2028.14 7500.00 0.00 270.00 6932.10 0.00 S 2028.14 W 0.00 2028.14 7573.90 0.00 270.00 7006.00 0.00 S 2028.14 W 0.00 2028.14 8000.00 0.00 270.00 7432.10 0.00 S 2028.14 W 0.00 2028.14 8500.00 0.00 270.00 7932.10 0.00 S 2028.14 W 0.00 2028.14 8873.90 0.00 270.00 8306.00 0.00 S 2028.14 W 0.00 2028.14 All data is in feet unless otherwise stated. Coordinates from Slot #lA and TVD from RKB 282' (282.00 Ft above mean sea level). Bottom hole distance is 2028.14 on azimuth 270.00 degrees from wellhead. Total Dogleg for wellpath is 73.24 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) MARATHON Oil Company Falls Creek Unit #l,FC #1 Falls Creek Field,Kenai Peninsula. Alaska ) PROPOSAL LISTING Page 2 Your ref : FC #1 Version #1 Last revised: 20-Jul-2001 Target name Geographic Location T.V.D. Targets associated with this wellpath Revised Rectangular Coordinates Target 1 5006.00 ......-.....--......---..--............-......-----........------------.......---..-------....--..-......------..---...............------..........-....---- O.OON 1750.00W 20-Jul·2001 07/26/2001 14:44 90726 7f.rr::¡,~ BAKER HUGHES P '~JQ MARATHON Oil Company Falls Creek Unit #1 FC #lRd Slot #lA Fal's Creek Fie1d Kenai Peninsu1a. A1aska PRQPOSAL LISTING by Baker Hughes INTEQ Your ref : FC#lRd VersionUl Our ref : prop4805 license ~ Date printed: 26·Jul-2001 Date created: 20-Ju1-2001 Last revised: 26·Jul·2001 PAGE 131 Field is centred on 242770.254.0.0aO.999.00000.N structure is centred an 242770.254.2267493.144,999.00000,N Slot location is n60 12 15.876.w151 25 46.590 S10t Grid coordinates are N 2269452.431. E 239926.624 Slot local coordinates are 1898.00 N 2885.00 W Projection type; alaska - lone 4, Spheroid; Clarke · 1866 _~~~ ~~ Reference North is True North ~ ~" ,,~c.) ,~ ~~ ~~'? ~ \..r>- ~ ~~ . , 87/26/2081 14:44 907267Fr'Qj BAKER HUGHES P ·::rYQ PAGE 02 MAR~THON Oil Company PROPOSAL LISTING Page 1 Falls Creek Unit #l.FC #lRd Your ref : FC#lRd Version#l í-alls Creek Field.Kenai Peninsula. Alaska Last revised: 26-Jul·2001 Measured Inclio Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Oe,grees Degrees Depth COO R 0 I N ATE S Oeg/l00ft Sect East;ng Northing 3150.00 16.63 268.34 3093.59 167.575 370.06W 0.00 370.06 239553.07 2269292.83 3170.00 19.03 268.34 3112.62 167.755 376.18W ¡2.00 376.18 239546.95 2269292.78 3200.00 20.46 269.61 3140.86 167.935 38S.3lW 5.00 386.31 239536.82 2269292.82 33QO.00 25.30 272.85 3232.97 166.985 425.16W 5.00 425.16 239498.00 2269294.60 3400.00 30.19 275.10 3321.44 163.665 471.5BW 5.00 471. 58 239451.66 2269299.89 3500.00 35.11 276.78 3405.61 158.045 525.22W 5.00 525~22 239398.16 2269305.68 3600.00 40.05 278.09 3484.84 150.125 585.66W 5.00 585.66 239337.89 2269314.59 3688.50 44.43 279 . 04 3550.35 141.24$ 644.47W 5.00 644.47 239279.29 22.69325.02 4000.00 44.43 279.04 3772.80 106.995 859.81W 0.00 859.81 239064.74 2269363.87 4392.60 44.43 279.04 4053.18 63.835 1131. 22W 0.00 1131.22 238794.33 2269412.64 4400.00 44.28 279.00 4058.47 63.025 1136.33W 2.00 l136.33 23B789.23 2269413.76 4500.00 42.30 278.55 4131.25 52.555 1204.09W 2.00 1204.09 238721. 71 2269425.68 4,600 . 00 40.33 278.07 4206.36 43.00S 1269.42W 2.00 1269.42 238656.61 2269436.63 4700.00 38.36 277.54 4283.69 34.385 1332.22W 2.00 1332.22 238594.00 2269446.58 4800. DO 36.39 276.97 4363.15 26. ilS ¡392.43W 2.00 1392.43 238533.97 2269455.54 4900.00 34.42 276.34 4444.66 19.99$ 1449.98W 2.00 1449.98 238476.59 2269463.49 5000.00 32.46 275.64 4528.10 14.235 lS04.7BW 2.00 1504.78 238421.92 2269470.42 5100.00 30.50 274.86 4613.38 9.44S 1556.78W 2.00 ).556.78 238370.04 2269476.32 5200.00 28.55 273.99 4700.39 5.63$ 1605.90W 2.00 1605.90 238321.01 2269481.19 5300. DO 26.60 273.00 4789.03 2.795 1652.10W 2.00 1652.10 238274.88 22694B5.01 5400.00 24.66 211 . 87 4879.18 0.945 1695.32W 2.00 1695.32 238231.72 2269487.79 5500.00 22.73 270.56 4970.75 0.075 1735.49W 2.00 1735.49 236191.51 2269489.52 5538.l2 22..00 270.00 5006.00 O.OON 1750.00W 2.00 1750.00 238).17.07 2269489.90 5604.79 21.00 270.00 5068.03 O.OON 1774.43W 1.50 1774.43 238152.64 2269490.42 5704.79 19.50 270.00 5161.84 O.OON 1809.04W 1.50 1809.04 238118. 04 2269491.16 5804.79 18.00 270.00 5256.53 O.DON l841.19W 1.50 1841.19 238065.90 2269491.85 5904.79 16.50 270.00 5352.03 O.QON 1870.84W 1.50 1670.84 238056.26 2269492.49 6004.79 15.00 270.00 5448.28 O.OON 1897.98W 1.50 1897.98 238029.12 2269493.07 6104.79 13.50 270.00 5545.20 O.OON 1922.60W 1.50 ).922.60 238004.51 2269493.60 6204 . 79 12.00 270.00 5642.73 O.DON 1944.67W 1.60 1944.67 237982.45 2269494.07 6304. 79 10.50 270.00 5740.80 O.OON 1964. laW 1.50 1964.18 237962.95 2269494.49 6404. 79 9.00 270.00 5839.36 a.CON 19B1.lJ.W 1.50 1981. n 237946.02 2269494.85 6504.79 7.50 270.00 593B.32 O.DON 1995.46W 1.50 1995.46 237931.67 2269495.16 6604. 79 6.00 270.00 6037.62 a.DON 2007.21W 1.50 2007.21 237919.92 2269495.41 6704. 79 4.50 270.00 6137.20 C.OON 2016.36W 1.50 2016.36 237910.77 2269495.60 6804. 79 3.00 270.QO 6236.98 O.OON 2022.90W 1.50 2022.90 237904.24 2269495.74 6904. 79 1.50 270.00 6336.90 O.OON 2026.83W 1.50 2026.83 237900.31 2269495.83 7004.79 0.00 270.00 6436.89 O.oos 2028.14W 1.50 2028.14 237899.00 2269495.85 7500. 00 0.00 270.00 6932.10 0.005 2028.14W 0.00 2028.14 237899.00 2269495.85 7573.90 0.00 270.00 700'6.00 O.OOS 2028.14W 0.00 2026.14 237899.00 2269495.85 BOOO.OO 0.00 270.00 7432.10- O.OOS 2028.14W 0.00 2028.14 237899.00 2269495.as 8500.00 0.00 270.00 7932.).0 O.OOS 2028.14W 0.00 2028.14 237899.00 2269495.85 8873.90 0.00 270.00 8306.00 0.005 2028.141,1 0.00 2028.14 237899.00 2269495.85 All data in feet unless otherwise stated. Calcu1ation uses minimum curvature method. Coordinates from Slot #1A and TVD from RKB 282' (282.00 Ft above mean sea level). Bottom hole distance is 2028.14 on azimuth 270.00 degrees from wellhead. Total Dogleg for we11path is 73.24 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 270.00 degrees. Grid is alaska· Zone 4. Grid coordinates in FEET a~d computed usi~g the Clarke· 1866 spheroid 07/26/2001 14:44 90726761:'7.1 ) BAKER HUGHES J"'TfQ PAGE 03 Presented by Baker Hughes INTEQ MARATHON Oi 1 Company Falls Creek Unit #l.FC #lRd Fa" s Creek r'ield,Kenai Penìnsul ð. Al aska PROPOSAL LISTING Page 2 Your ref ~ FC#lRd Version#l Last revised: 26-Jul-2001 Targets associated with this wellpath ._ .._ ... r- - ... Target name Geographic Location LV.D. Rectangu1ar Coordinates Revised ...__....r____~..P----4..--_....~---.·.-·--··.--·~···---_...P--_·..--_···~P-_·-...---_··.-·_··."---···--_·· Target 1 5006.00 3797.005 863.00E 20-Jul-2001 I Flow Nipple I 13 5/8" 5M Annular Prevent~r 135/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves 13 5/8" 5M Single Ram Preventer ) I -----. I Marathon Oil Well FC-1 rd BOP Stack , -. I Flow Line I I < 1 /1 JI IChoke(]@[I xl t ~ "> I 1 " ./ / 1 I < ~~ IxIlxI)KiII I I I~:)/ 13 5/8" 5M Cross I ~ I Pipe Ram I I Blind Ram I ) 1 I "' "- I I < I Pipe Ram I " ./ < I 1 í 1 1 '\ 3 1/8" 5M Hydraulically Operated Valve 3 1/8" 5M Manually Operated Valve ') Marathon Oil Well FC-1 rd Choke Manifold ITo Gas Buster I To Blooey Line ~ I ~ I , [J@(j , ( ~ ( I L--,I ;=( r-~ ø ø ~ J ----... ) Bleed off Line to Shakers CJ@(~ ~ I I ( ~ L--,I ) r-1 ~ L-- J@(J® 0 J@(J®l. '\ I L-1 I I 13" 5M Valves I Î t 2 9/1611 10M Swaco Hydraulically Operated Choke ~ IFrom BOP Stack 3 1/811 5M Manually Adjustable Choke ) ) MARATHON OIL COMPANY ALASKA REGION FALLS CREEK #1 rd MONOBORE EVALUATION · Falls Creek #1 rd is designed as a 4 V2" monobore completion to surface (cemented to 2650'). · No annular production is intended from Falls Creek #1. . This well will not be produced until such time as a pipeline is constructed. · Falls Creek #1 will be left with a 3.989" backpressure valve, a 4" 5M gate valve, and a 6V2" Otis tree connection. TOPIC Erosional Velocity Corrosion DISCUSSION . Eventual flow will be out 4" wing valves. · The highest potential for erosive flow exists at the BPV threads. · The back pressure valve threads inside these outlets have an 10 of 3.989" as the smallest restriction. . · The erosional velocity at the BPV threads is reached at rates greater than 29 MMCFGPO (based upon API RP14E). · The Falls Creek #1 Tyonek zone is not anticipated to be capable of 29 MMCFGPO production. · Marathon plans to produce the well below erosive limits. · The partial-pressure of CO2 is less than 7.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive (Based on KGF Tyonek). · There is no H2S gas produced from the Falls Creek Tyonek. · Corrosion of the casing is highly unlikely. Burst/Collapse of Casing and . Pressure is not anticipated on the 9-5/8" casing (5750 psi burst, Production Tubing 3090 psi collapse). · Worst-case forces will not exceed 47% of the rated 4%" production tubing burst or collapse (4%" will be cemented to 2650'). /~ ) ') { "\. SURFACE USE PLAN FOR FALLS CREEK #1 rd WELL Surface Location: NE 1/4 of SW 1/4, Sec. 6, T1 N, R12W, S.M. 1. Existing Roads Existing roads that will be used for access to the FC #1 rd well are shown on the attached map. Ninilchik, Alaska, is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed An existing road on the Pederson property will be used for access to the pad. 3. Location of Existing Wells Well FC #1 rd is the only well drilled from the pad. The nearest well is the Falls Creek # 43-6, which is approximately 4000 feet away. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply An existing water well will be used to make and maintain the drilling mud. 6. Construction Materials No construction materials will be need for this project. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage N:\DRLG\WELLS\FallsCreek #1\SURFUSE.doc t ) ) Surface Use Plan Marathon Falls Creek #1 rd Well Page 2 All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of FC #1 rd. 10. Surface Ownership Harold Lee Pederson is the surface owner of the land at the Marathon Falls Creek#1 rd well. 11. Operator's Representative and Certification ) Surface Use Plan Marathon Falls Creek #1 rd Well Page 3 ') I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: July 25, 2001 Name & Title: C?~ Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 Drilling Superintendent .... '.' . I '¡; '¡ r . " " ..1 . . ~:' ;': '.: " ,'I ','. 13"'-r ~ 17-r. r-r U At. P1U. PIT '. r 5" I ~~. . -.¡ - - _ .. ~~1IJI "_'. . '. - -. -, ~L-_--~-)::G, '...-' . .., ~. .. '~ B" ~4·-t" 1'-0- ._-~ ...... .. . ""'-' , )( I \&I. I .... I.. < w 1 :r: I SV 9L ' , ti . >- I A76ØO, pI. .~. , 1 I J ,I T I I .. ,I '0 .....al- I I , , . ~ - I , . . . ,I 5W 9L A-600 fT --- 1G1P MitTATœ " a .¡ t~·i· , . " e t· /~, ", ~ ---"J ~ , 75 'HP' 6 X S: 14~· ' -4i..... tI.ID TJUDf 2' . ·l.:r:rm. r ·I~. '!I "-- ¡. " ." . .C" ~ ..... .. .: .', , . ~ ~ ~ ~,1 '. t ~, i. . *' "'" . 75'f-p 6X 5. . 1-4·' ',"75 HP ; 6' X'S . 14·' .K: ~ --t,'-r w-e- ~ 'IMP ? ]C U' : . ¡'a·am, ~sp. .... " - --_r .....~ \.. . ~~.- , . - 4 JI.ID ~~: ~ ... : ~... ,'" ~ " i .r,~~, tiP : 6 )fS 141' Ii } ", , .', .",i, ' KIIJM,Y 3" X l2' , I, þ:' .Q: ~ .¡ ·1 .~. .' .. 9 I ' '! ' . ," '. .f:·, ':.,: ',' . , L..........:..:.-~__.:-.. I '. . ' .. . I I, . 1 ,. : .& J ,I ':! I~~::~:;~\. .. J'POORJ3OY i :, tDEGAS;S£Ri ':,:-~\~~.~:~>' . W'-o'·. 'I . . ........ .. ¡up , \ 1I.Jifr" . ,,~ . ~J I' IX W '.",~ ".: ~ L: .M '~ ~. R· '. " . . . , ' ), , . , ' ", " r.... ' ') , , M MARATHON Marathon Oil Company July 25, 2001 Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Re: Well re-naming Dear Mr. Maunder: ') Alaska Region Domestic Production P.o. Box 196168 Anchorage~ AK 99519-6168 Telephone 9071561-5311 Fax 9071564006489 3/~OI Marathon Oil Company requests that Well Falls Creek 13-6 be re-named as FC #1. If it is sidetracked, it will be re-named FC #1 RD. If you have any questions concerning this matter, please contact me at 564-6319. Sincerely, &1(?-r- RE.CE.\\lE.O JUl 2 S lGG' commissioo . &. Gas COf'S. þ..\asv..a 0\\ ~oc\'lO{age Peter K. Berga Drilling Superintendent bjv ) Alaska HÐgion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 25, 2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501 Reference: Well FC #1 Dear Mr. Maunder: Enclosed is the application for permit to drill the referenced well and a check for $100.00. Please advise if additional information is required. Sincerely, c?/(~ P. K. Berga Drilling Superintendent PKB:bjv N :Drlg/FallsCreeklaogcclt.doc Enclosure RECEIVED JUl 2 5 2001 Alaska Oil & Gas Cons Comm' , , ISSlon Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. 1a. Type of Work DrillD Re-EntryD 2. Name of Operator MARATHON OIL COMPANY ) STATE OF ALASKA ) g'","O',""I"¡;09~"44-10IAOGCCPZ ALAS't<..A OIL AND GAS CONSERVATION COMMI3SION f(o / PERMIT TO DRILL !7r 210 AAC 25.005 / Re-Drill[K 1b. Type of well. Explorat0rG Stratigraphic TesD Develop t oiD DeepenD ServiceD Development GaG Single ZoneD iple ZoneŒ 5. Datum Elevation (OF or KB) 10. Field and Pool 282' Falls Creek/T 6. Property Designation 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1899' FSL & 252' FEL See 6, T1 N, R12\¡\¡ At top of Productive Interval 1899' FSL & 2002' FEL See 6, T1N, R12\¡\¡ At Total Depth 1899' FSL & 2280' FEL See 6, T1 N, R12\¡\¡ 12. Distance to Nearest Property Line(unit boundary 1325 feet 16. To be Completed for Deviated Well: Kickoff Depth 3150 feet Maximum Hole Angle 18. Casing Program Size Hole Casing Weight 26" 20" 97 18 5/8" 13.375" 54.5 121/4" 9 5/8" 40 6 3/4" 41/2" 11.6 7. Unit or Property Name Falls Creek Unit 8. Well Number Falls Creek #1 rd 9. Approximate Spud Date 7/27/2001 11. Tyg Bond (see 20 AAC 25.025) anket Surety Number 5194234 Amount $200000 15. Proposed Depth 13. Distance to Nearest Well feet (MD and TVD) 8874'md/8306' tvd 4000 feet 44 0 17. Anticipated Press E (see 20 AAC 25.035 (e) (2)) Maximum Surface ~C\):> pslg at Total Depth (TVD) tting Depth Al.~ Bottom 8306' Specifications Grade Coupling ? ? Quantity of Cement (including stage data) In Place, wi 480 sacks In Place wi 1660 sacks In Place, wi 1884 sacks Length MD MD TVD 248' 0' 248' 248' 2468' 0' 2468' 2439' 3150' 0' 3150' 3094' 8874' 0' 8874' 8306' J-55 N-80 L-80 STC LTC LTC R~CEIVED ~Ç) eº 1..j \"- ( .4- ~ JUL 25 ZOO I ðOc) ~Ic ska Oil & Gas Cons. Commission Anchorage Falls Creek Unit well Falls Creek #1 will e plugged back according to AOGCC regulations to 3150' MD and si~etracked. Falls Creek #1st will be d' ectionally drilled to an estimated total depth of 8874' MD/8306' TVD from the existing Falls Creek Unit 10cation.Th production interval will be cased with 4 1/211 casing and cemented. Marathon's drilling rig will be used to drill and c mplete this well. The following documents are attached: Drilling Program, Surface se plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Property Pla(R] BOP Sketch[K Drilling Fluid prograª Ti e vs Depth PloD Refraction AnalYSiU 21. I hereby certify that the for oing is true and correct to the best of my knowledge Phone: 564-6319 Title Drilling Superintendent Diverter SketcG Seabed Repor[] Drilling PrograrrCK] 20 AAC 25.050 RequirementO API Number 50- /33 - 2.,0 2.'19 - (3 J Conditions of Appro al Samples Required DYes ~No Mud Log Required DYes ~No Hydrogen Sulfide easures DYes ~ No Directional Survey Required ,g]Yes D No Required Worki g Pressure for BOPE D2M m3M D5M D 10M D 15M Other: Signed Permit Number Approved by Form 10-401 Rev. 12-1-85 Commission Use Only Approval Date Date: ;> JZ.r /15/ See Cover Letter For Other Requirements Commissioner by order of the Commission Date Submit in Triplicate nRIG1f\IAI ) Marathon Oil Company Alaska Region Prepared By: P. K. Berga Approved By: Date: 07/25/01 Drilling Program Well: Falls Creek #1 RD AFE: 1506101 Area: Falls Creek Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No. 1 Geologic Program Depth Target Locations FSL FEL Block MD Surface 1899' 252' Sec. 6, T1N, R12W, S.M. 21' ( 15 ' OKB) Tyonek T-1 1899' 2002' Sec. 6, T1N, R12W, S.M. 5538' Tyonek T-3 1899' 2280' Sec. 6, T1N, R12W, S.M. 7574' Bottom Hole 1899' 2280' Sec. 6, T1N, R12W, S.M. 8874' OKB=Original Kelly Bushing TVD 21'OKB ( 15 ' OKB) 5006' 7006' 8306' Tolerance RKB Elevation: RKB to MSL=282, (original hole/well 276') GL-MSL=261, Total Depth: TVD 8306' MD 8874' Max. Angle 44 Course 270 Abnormal Pressures: N/A Subnormal Pressures:N/A Coring and DST's: N/A Mud Logging: Contractor: Services: Epoch Start Depth: Below KOP Basic with GCA, shale density, temperature in and out, sample collection. 30' samples to TD Logging Program: Contractor To be determined Surface Production LWD NA NA Wireline Logs GR/AIT/DSI/NGT FC #lrd Drilling Program Page 1 of 8 ') ) Drilling Progr~ Summary Production: The existing wellbore will have been plugged back to <= 3150' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at ±3150' MD. Test plug and casing to ~OO psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees right of highside for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (13.5 PPG anticipated). Drill a 6 3/4" hole to 8874' MD/ 8306' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 4 1/2" production casing and cement per the attached program. Proceed with completion program. Casing Progr~ API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension ( in) From (MD) (pp f ) Grade Type ( in) (psi) (psi) (K Ibs) (MD) 9 5/8" 0' 3150' 40.0 N-80 BTC 12 1/4" 5750 3090 916 4 1/2" 0' 8874' 12.6 L-80 BTC 6 3/4" 7780 6350 267 Note: The 9-5/8" casing is already installed. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (pp f ) Grade (TVD) (ppg) (ppg) (ps i) Burst Collapse Tension 9 5/8" 40 N-80 3094' 13.5 9.0 1043 2.6 3.6 NA 4 1/2" 12.6 L-80 8306' 9.0 1490 2.13 1. 43 1. 83 FC #lrd Drilling Program Page 2 of 8 ) ) Directional Program Directional Co: Baker Hughes Inteq KOP: 3150 Direction: 268 Gyro Co: To be determined Build Rate: 5.0 To: 44 deg @ 3550' TVD Drop Rate: 1. 75 ave. To: 0 deg @ 6437' TVD Drop Depth: 4400' MD/ 4058' TVD Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below KOP past interference. General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 9 5/8" Intermediate Casing @ 3094' TVD MASP [(PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)] MASP [(9.0 * 0.052 * 8306) - (0.3 * 0.052 * 9.0 * 8306) - (0.7 * 0.1 * 8306)] MASP 2472 psi 4 1/2" Production Casing @ 8306' TVD* l.r>.t' -.~-.Q.:.O 5 2 * TVD f - [9.0 * 0~2 * 8 2932 psi (GG * TVDf)] - (0.1 * 8306')] FC #lrd Drilling Program Page 3 of 8 Cementing Program Production Casing Size: 4 1/2" Lead Slurry: Top of Cement: Specifications: Compress Strgth: Tail Slurry: Top of Cement: Specifications: Compress Strgth: Total Volume: ), ) Contractor: BJ Services Setting Depth: 8874' MD/ 8306' TVD Annular Volume to 2650' with 6 3/4" gauge hole: 932 ft3 Density:~ ppg, Yield: 2.08 ft3/sx, Sx: 300 sx, cf: 624 ft3 2650'MD/ 2612' TVD Class G + additives Mixed w/ fresh water 500 psi in 10 2000 psi in 16 hrs hrs, Density:~ ppg, Yield:~ ft3/sx, Sx: 600 sx, cf: 690 ft3 5508'MD/ 5006' TVD - - Class G + additives Mixed w/ fresh water 500 psi in 6 hrs, 3600 psi in 24 hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions. 1314 ft3, ~% Open Hole Excess, wac Time: 6 hrs FC #lrd Drilling Program Page 4 of 8 Diverter and BOP Program The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing ( in) (ps i) (ps i) Size & Rating (psi) Intermediate pd" 1500 (1 ) 13-5/8" 5M Annular 250/3000 ~ 9 5/8" 'd4'O (9.2 (1 ) 13-5/8" 5M Blind ram 250/3000 ppg (2 ) 13-5/8" 5M Pipe ram 250/3000 mud) Production / ~ 2500 ( 1) 13-5/8" 5M Annular 250/3000 ./ (10.0 ( 1) 13-5/8" 5M Blind ram 250/3000 \i " (2 ) 13-5/8" 5M Pipe ram 250/3000 '" , ?'\\) ppg ~ mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 9 5/8" Intermediate Casing at 3094' TVD CTPMASP = 2472 psi CTPBurst = 5750 * 0.7 - ((9.0-8.3) * 0.052 * 3094) Test to 2500 psi 3912 psi 4 1/2" production Casing at 4050' TVD CTPMASP = 2932 psi Test to 3000 psi CTPBurst = 7780 * 0.7 - ((9.0-8.3) * 0.052 * 8306) 5144 psi FC #lrd Drilling Program Page 5 of 8 ') ) Mud Program Contractor: Ml Drilling Interval (TVD) From 3094' Fluids Mud weight (ppg) 9.0 - 9.5 Water Loss <8 Mud Type Flo Pro/KCl To 8006' Wellhead Program Manufacturer Model Tubing Head Tubing Hanger Vetco Annular Flow 11" 3M x 9 5/8" 5M 9 5/8" x 4-1/2 Mandrel Tubing hanger Detailed Drilling Procedure Fo~tion Leakoff Test Inter.mediate casing shoe will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the lADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Bit Program The following guidelines are recommended for use on this well. Interval (MD) 3150' - 8874' Bit Size (in) 6 3/4" Bit Model Smith-To be determined lADC Code WOB ( k lbs) RPM FC #lrd Drilling Program Page 6 of 8 ') ') Drill String Item 3 1þ" HWDP,3 1þ" IF Ppf 24.4 Makeup Torque 12000-13200 ft.-lbs. Max Pull -Premium 248,000 Ibs 4", 8-135, HT 38 15.53 13,500-19,800 ft.-lbs. 29,000 ft.-lbs. 403,500 Ibs. 5" HWDP, 41þ" IF 49.3/53.6 543,000 Ibs. Hydraulics Program Rig mud pumps available are shown below. Install 4 1/2 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model ( in) ( in) (97% eff) ( spm) Oilwell A 600 PT 4 ¥2" 8" 3207 1. 6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 Oilwell A 600 PT 5 ¥2" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) ( in) ( gpm) (psi) (fpm) ( ppg ) (32"s) 8874' 6 3/4" +/-265 2200 - 175 9.5 14,14,14 2800 Remarks Motor Drilling Note: 4 1/2" liners are recommended. FC #lrd Drilling Program Page 7 of 8 ') OPERATIONAL PROCEDURE 1. Abandon existing perforations according to program filed with AOGCC. RIH and set CIBP at +/- 3150' md. Test plug and casing to 2500 PSi~ MU and RIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside casing exit. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 13.5 ppg anticipated). 2. 3. 4. Drill a 6 3/4" hole to 8874' MD/ 8306' TVD per the attached directional program. Backream each stand. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. 5. At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH. Run logs as per geology requirements. Make wiper trip. POOH laying down drill pipe. Pull wear bushing. 6. Install and test casing rams. 7. Locate pump in sub and safety valve. Function safety valve and place on rig floor. Record function test in IADC book. RU and run 4 1/2" casing. 8. Cement casing as per the attached cementing program. Displace cement with KCL. 9. Test hanger. Set BPV. N/D BOPE and N/U and test tree. FC #lrd Drilling Program Page 8 of 8 Flow Nipple I 13 S/8" SM Annular Preventer 13 S/8" SM Double Ram Preventer 3 1/8" SM Manually Operated Valves 13 S/8" SM Single Ram Preventer I ----. I Marathon Oil Well FC-1 rd BOP Stack ) -. I Flow Line I I ( 1 /1 ,¡ IChoke(J0[I xl t ~ "> / I I 1 1 ) ( I Pipe Ram I I Blind Ram I ) I 1 " "- 1 1 ( I Pipe Ram I "- / 1 1 \ ( 1 I í ~~ IxlIxl)KiII I 1 I~:)/ 13 S/8" SM Cross I ~ 3 1/8" SM Hydraulically Operated Valve 3 1/8" SM Manually Operated Valve ~ } [J®[] ~ } ~J®:= t ~ ( ~ L-~ ~=( ~1 ~ ~ l ------.. ) ITO Gas Buster I J®[ , Marathon Oil Well FC-1 rd Choke Manifold To Blooey Line Bleed off Line to Shakers ~ ) ( ~ L-J (-} o J®[J0l. L-) I i t 13" 5M Valves 2 9/16" 10M Swaco Hydraulically Operated Choke ~ I From BOP Stack 3 1/8" 5M Manually Adjustable Choke Cr~ot~d by :sutherla Dote plotted: 2J-Jul-2001 Plot Reference is FC #1 Version II. Coordinates ore in feet reference Slot #1A. True Vertical Depths ore reference RK8 282'. MARATHON Oil Company --- Boker Hughe:s INTEQ --- Structure: Falls Creek Unit #1 Well: FC #1 Location : Kenai Peninsula, Alaska 800 - [Ð 1200 - 1600- 2000 - 2400 - 2800 - 3200 - ~ 3600 - ..- () () '+- 4000 - '-" ..t: ..- a. 4400 - () 0 0 4800 - 0 - "- () > 5200 - () :J "- 5600 - l- I V 6000 - 6400 - 6800 - 7200 - 7600 - 8000 - 8400 - 8800 400 o Field : Falls Creek Field 2200 I 2000 <- West (feet) 1800 1200 400 1600 1400 1000 800 600 200 o 200 - 200 ./ - 0 U) --- 0 -- -- c - 1-0 - 200 ::r ""' X) ..... (þ - 400 (þ - '-" I - 600 V - 800 KOP 20.46 25.30 DLS: 5.00 deg per 100 ft .30.19 35.11 44.43 End of Build/Turn End of Drop Target 2 ---- WELL PROFILE DATA ---- ----- PoInt ----- 110 In. D!, 'NO "- ~t V. Set Dov/loo KOP 3150.00 16.&3 211II.34 3an.SII -167.67 -370.06 37O.DII 0.00 Con~nu. Bu~d 3170.00 19.03 2~ 3' 12.82 -167.75 -376.16 375.18 12.00 End of BuIId/Tum 36111!.5( 404A1 279.00- 355<I.J5 -141.24 -044.47 644.47 s.oo End of Hold 4.1JII2.eo 404.411 279.00- 00:1.1.'8 -615.5 -1131,22 1131.22 0.00 TorQOt ~12 22.00 270.00 :KJD1i.00 0.00 -1 7SO.00 IISO.oo 2.00 Enol of Drop 7004.711 0.00 270.00 ~6.1111 0.00 -20211. I 4 2028.14 1.50 En4 of Hold "73.iO 0.00 270.00 7OO1i.00 0.00 -2028.14 2028.14 0.00 T.D. ð: End .1 Hold 1II".iO 0.00 270.00 S.5Oli.oo 0.00 -2028,14 21125.14 0.00 44.43 End of Hold 44.28 40.33 36.39 32.46 DLS: 2.00 deg per 100 ft 30.50 28.55 26.60 24.66 22.73 21.00 19.50 18.00 16.50 15.00 DLS: 1.50 deg per 100 ft 1.3.50 12.00 10.50 9.00 7.50 6.00 4.50 .3.00 1.50 0.00 :\ \.. , "- "- "- "- -.. ~ \.. , \ \, "- \ '\ , \ ~ , \ ~ ~ 1 + T I I I I I r I I I I I I I I ~ 400 800 1600 T.o. 2000 2800 1200 Vertical Section (feet) - > 2400 Azimuth 270.00 with reference 0.00 N, 0.00 E from Slot #1 A ) MARATHON Oil Company Falls Creek Unit #1 FC #1 Slot #1A Falls Creek Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref : FC #1 Version #1 Our ref : prop4805 License Date printed Date created Last revised 20-Jul-2001 20-Jul-2001 20-Jul-2001 Field is centred on 242770.254.0.000.999.00000,N Structure is centred on 242770.254,2267493.144,999.00000.N Slot location is n60 11 38.486.w151 24 54.492 Slot Grid coordinates are N 2265600.022, E 242477.659 Slot local coordinates are 1899.00 S 252.00 W Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ') ) MARATHON Oil Company PROPOSAL LISTING Page 1 Falls Creek Unit #l.FC #1 Your ref : FC #1 Version #1 Falls Creek Field.Kenai Peninsula. Alaska Last revised: 20-Jul-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 3150.00 16.63 268.34 3093.59 167.57 S 370.06 W 0.00 370.06 3170.00 19.03 268.34 3112.62 167.75 S 376.18 W 12.00 376.18 3200.00 20.46 269.61 3140.86 167.93 S 386.31 W 5.00 386.31 3300.00 25.30 272.85 3232.97 166.98 S 425.16 W 5.00 425.16 3400.00 30.19 275.10 3321.44 163.68 S 471. 58 W 5.00 471. 58 3500.00 35.11 276.78 3405.61 158.04 S 525.22 W 5.00 525.22 3600.00 40.05 278.09 3484.84 150.12 S 585.66 W 5.00 585.66 3688.50 44.43 279.04 3550.35 141. 24 S 644.47 W 5.00 644.4 7 4000.00 44.43 279.04 3772.80 106.99 S 859.81 W 0.00 859.81 4392.60 44.43 279.04 4053.18 63.83 S 1131.22 W 0.00 1131.22 4400.00 44.28 279.00 4058.47 63.02 S 1136.33 W 2.00 1136.33 4500.00 42.30 278.55 4131.25 52.55 S 1204.09 W 2.00 1204.09 4600.00 40.33 278.07 4206.36 43.00 S 1269.42 W 2.00 1269.42 4700.00 38.36 277 .54 4283.69 34.38 S 1332.22 W 2.00 1332.22 4800.00 36.39 276.97 4363.15 26.71 S 1392.43 W 2.00 1392.43 4900.00 34.42 276.34 4444.66 19.99 S 1449.98 W 2.00 1449.98 5000.00 32.46 275.64 4528.10 14.23 S 1504.78 W 2.00 1504.78 5100.00 30.50 274.86 4613.38 9.44 S 1556.78 W 2.00 1556.78 5200.00 28.55 273.99 4700.39 5.63 S 1605.90 W 2.00 1605.90 5300.00 26.60 273.00 4789.03 2.79 S 1652.10 W 2.00 1652.10 5400.00 24.66 271.87 4879.18 0.94 S 1695.32 W 2.00 1695.32 5500.00 22.73 270.56 4970.75 0.07 S 1735.49 W 2.00 1735.49 5538.12 22.00 270.00 5006.00 0.00 N 1750.00 W 2.00 1750.00 5604.79 21.00 270.00 5068.03 0.00 N 1774.43 W 1.50 1774.43 5704 .79 19.50 270.00 5161.84 0.00 N 1809.04 W 1.50 1809.04 5804.79 18.00 270.00 5256.53 0.00 N 1841.19 W 1.50 1841.19 5904.79 16.50 270.00 5352.03 0.00 S 1870.84 W 1.50 1870.84 6004.79 15.00 270.00 5448.28 0.00 S 1897.98 W 1.50 1897.98 6104.79 13.50 270.00 5545.20 0.00 S 1922.60 W 1.50 1922.60 6204.79 12.00 270.00 5642.73 0.00 S 1944.67 W 1.50 1944.67 6304.79 10.50 270.00 5740.80 0.00 S 1964.18 W 1.50 1964.18 6404.79 9.00 270.00 5839.36 0.00 S 1981.11 W 1.50 1981.11 6504.79 7.50 270.00 5938.32 0.00 S 1995.46 W 1.50 1995.46 6604.79 6.00 270.00 6037.62 0.00 S 2007.21 W 1.50 2007.21 6704.79 4.50 270.00 6137.20 0.00 S 2016.36 W 1.50 2016.36 6804.79 3.00 270.00 6236.98 0.00 S 2022.90 W 1.50 2022.90 6904.79 1. 50 270.00 6336.90 0.00 S 2026.83 W 1.50 2026.83 7004.79 0.00 270.00 6436.89 0.00 S 2028.14 W 1.50 2028.14 7500.00 0.00 270.00 6932.10 0.00 S 2028.14 W 0.00 2028.14 7573.90 0.00 270.00 7006.00 0.00 S 2028.14 W 0.00 2028.14 8000.00 0.00 270.00 7432.10 0.00 S 2028.14 W 0.00 2028.14 8500.00 0.00 270.00 7932.10 0.00 S 2028.14 W 0.00 2028.14 8873.90 0.00 270.00 8306.00 0.00 S 2028.14 W 0.00 2028.14 All data is in feet unless otherwise stated. Coordinates from Slot #lA and TVD from RKB 282' (282.00 Ft above mean sea level). Bottom hole distance is 2028.14 on azimuth 270.00 degrees from wellhead. Total Dogleg for wellpath is 73.24 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) " MARATHON Oil Company Falls Creek Unit #1,FC #1 Falls Creek Field,Kenai Peninsula. Alaska PROPOSAL LISTING Page 2 Your ref : FC #1 Version #1 Last revised: 20-Jul-2001 Targets associated with this wellpath --------- ------ Target name Geographic Location T.V.D. Rectangular Coordinates Revised - ...--- -- ........... ...--.......... --- -- --- --........ --.... ..........- --.. -------...... --.....-- ..----.......-----.... -- ---............-....... --............- ......- -..- Target 1 5006.00 O.OON 1750.00W 20-Jul-2001 ') ) MARATHON Oil Company Falls Creek Unit #1 FC #1 Slot #IA Falls Creek Field Kenai Peninsula. Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License FC #1 Version #1 prop4805 Date printed Date created Last revised 23-Jul-2001 20-Jul-2001 20-Jul-2001 Field is centred on 242770.254,0.000,999.00000,N Structure is centred on 242770.254.2267493.144,999.00000,N Slot location is n60 11 38.486,wI51 24 54.492 Slot Grid coordinates are N 2265600.022, E 242477.659 Slot local coordinates are 1899.00 S 252.00 W Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North " . ) MARATHON Oil Company PROPOSAL LISTING Page 1 Falls Creek Unit #l,FC #1 Your ref : FC #1 Version #1 Falls Creek Field,Kenai Peninsula, Alaska Last revised: 20-Jul-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Dept h Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 3150.00 16.63 268.34 3093.59 167.57S 370.06W 0.00 370.06 242104.11 2265440.42 3170.00 19.03 268.34 3112.62 167.75S 376.18W 12.00 376.18 242097.99 2265440.37 3200.00 20.46 269.61 3140.86 167.93S 386.31W 5.00 386.31 242087.85 2265440.41 3300.00 25.30 272.85 3232.97 166.98S 425.16W 5.00 425.16 242049.03 2265442.19 3400.00 30.19 275.10 3321. 44 163.68S 471. 58W 5.00 471. 58 242002.70 2265446.48 3500.00 35.11 276.78 3405.61 158.04S 525.22W 5.00 525.22 241949.19 2265453.27 3600.00 40.05 278.09 3484.84 150.12S 585.66W 5.00 585.66 241888.93 2265462.48 3688.50 44.43 279.04 3550.35 141.24S 644.47W 5.00 644.4 7 241830.32 2265472.61 4000.00 44.43 279.04 3772.80 106.99S 859.81W 0.00 859.81 241615.77 2265511.46 4392.60 44.43 279.04 4053.18 63.83S 1131. 22W 0.00 1131. 22 241345.36 2265560.43 4400.00 44.28 279.00 4058.4 7 63.02S 1136.33W 2.00 1136.33 241340.27 2265561.35 4500.00 42.30 278.55 4131. 25 52.55S 1204.09W 2.00 1204.09 241272.75 2265573.27 4600.00 40.33 278.07 4206.36 43.00S 1269.42W 2.00 1269.42 241207.64 2265584.22 4700.00 38.36 277 .54 4283.69 34.38S 1332.22W 2.00 1332.22 241145.04 2265594.17 4800.00 36.39 276.97 4363.15 26.71S 1392.43W 2.00 1392.43 241085.01 2265603.13 4900.00 34.42 276.34 4444.66 19.99S 1449.98W 2.00 1449.98 241027.62 2265611.08 5000.00 32.46 275.64 4528.10 14.23S 1504.78W 2.00 1504.78 240972.96 2265618.01 5100.00 30.50 274.86 4613.38 9.44S 1556.78W 2.00 1556.78 240921.08 2265623.91 5200.00 28.55 273.99 4700.39 5.63S 1605.90W 2.00 1605.90 240872.04 2265628.78 5300.00 26.60 273.00 4789.03 2.79S 1652.10W 2.00 1652.10 240825.92 2265632.60 5400.00 24.66 271.87 4879.18 0.94S 1695.32W 2.00 1695.32 240782.75 2265635.38 5500.00 22.73 270.56 4970.75 0.07S 1735.49W 2.00 1735.49 240742.60 2265637.11 5538.12 22.00 270.00 5006.00 O.OON 1750.00W 2.00 1750.00 240728.10 2265637.49 5604.79 21. 00 270.00 5068.03 O.OON 1774.43W 1.50 1774.43 240703.68 2265638.01 5704.79 19.50 270.00 5161.84 O.OON 1809.04W 1.50 1809.04 240669.07 2265638.75 5804.79 18.00 270.00 5256.53 O.OON 1841.19W 1.50 1841.19 240636.94 2265639.44 5904.79 16.50 270.00 5352.03 O.OOS 1870.84W 1.50 1870.84 240607.29 2265640.08 6004.79 15.00 270.00 5448.28 O.OOS 1897.98W 1.50 1897.98 240580.16 2265640.66 6104.79 13.50 270.00 5545.20 O.OOS 1922.60W 1.50 1922.60 240555.55 2265641.19 6204.79 12.00 270.00 5642.73 O.OOS 1944.67W 1.50 1944.67 240533.49 2265641.66 6304.79 10.50 270.00 5740.80 O.OOS 1964.18W 1.50 1964.18 240513.98 2265642.08 6404.79 9.00 270.00 5839.36 O.OOS 1981.11W 1.50 1981.11 240497.05 2265642.44 6504.79 7.50 270.00 5938.32 O.OOS 1995.46W 1.50 1995.46 240482.71 2265642.75 6604.79 6.00 270.00 6037.62 O.OOS 2007.21W 1.50 2007.21 240470.96 2265643.00 6704.79 4.50 270.00 6137.20 O.OOS 2016.36W 1.50 2016.36 240461.81 2265643.19 6804.79 3.00 270.00 6236.98 O.OOS 2022.90W 1.50 2022.90 240455.27 2265643.33 6904.79 1. 50 270.00 6336.90 O.OOS 2026.83W 1.50 2026.83 240451.35 2265643.42 7004.79 0.00 270.00 6436.89 O.OOS 2028.14W 1.50 2028.14 240450.04 2265643.45 7500.00 0.00 270.00 6932.10 O.OOS 2028.14W 0.00 2028.14 240450.04 2265643.45 7573.90 0.00 270.00 7006.00 O.OOS 2028.14W 0.00 2028.14 240450.04 2265643.45 8000.00 0.00 270.00 7432.10 O.OOS 2028.14W 0.00 2028.14 240450.04 2265643.45 8500.00 0.00 270.00 7932.10 O.OOS 2028.14W 0.00 2028.14 240450.04 2265643.45 8873.90 0.00 270.00 8306.00 O.OOS 2028.14W 0.00 2028.14 240450.04 2265643.45 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from Slot #lA and TVD from RKB 282' (282.00 Ft above mean sea level). Bottom hole distance is 2028.14 on azimuth 270.00 degrees from wellhead. Total Dogleg for wellpath is 73.24 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 270.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke· 1866 spheroid · , ') Presented by Baker Hughes INTEQ ) MARATHON Oil Company Falls Creek Unit #l,FC #1 Falls Creek Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref : FC #1 Version #1 Last revised: 20-Jul-2001 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised -........-----.......----.....-----.......--....-......................------..------....------....----.....------.......-....--------.........--...... Target 1 5006.00 O.OON 1750.00W 20-Jul-2001 ') ) SURFACE USE PLAN FOR FALLS CREEK #1 rd WELL Surface Location: NE 1/4 of SW 1/4, Sec. 6, T1 N, R12W, S.M. 1. Existi ng Roads Existing roads that will be used for access to the FC #1 rd well are shown on the attached map. Ninilchik, Alaska, is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed An existing road on the Pederson property will be used for access to the pad. 3. Location of Existing Wells Well FC #1 rd is the only well drilled from the pad. The nearest well is the Falls Creek # 43-6, which is approximately 4000 feet away. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply An existing water well will be used to make and maintain the drilling mud. 6. Construction Materials No construction materials will be need for this project. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage N:\DRLG\WELLS\FallsCreek #1\SURFUSE.doc ) ) Surface Use Plan Marathon Falls Creek #1 rd Well Page 2 All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of FC #1 rd. 10. Surface Ownership Harold Lee Pederson is the surface owner of the land at the Marathon Falls Creek#1 rd well. 11. Operator's Representative and Certification ) \ j Surface Use Plan Marathon Falls Creek #1 rd Well Page 3 I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: July 25, 2001 Name & Title: (/~ Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 Drilling Superintendent --,._---,_..---,._---_._-----_._".----...-..._-----~------..--------,-- ------_._-'..__._-._~"--~-,,_.._-,,.,----,- ~--,-_._._-_..._.__._,-'---- -'-,-._--_.~--~-_.. ,--_..._---~_.._.~---,-_.-----~--..~-..~-- .----. .._--~- .-- ---...--~._,~--- ~ -.-.-..'-.- .__._-_._..'------~-~-.__._...---,_. -----.-.---.-.---.----.--..- --_._...._-_._,-----,-_..~---_.__. .._._._.,..._...__.._,..._..______.__..'__,__.__~___..~_.~.._~,_._.._'.'__.__,_._._...__,,__ .___._..___ _____...____.__. _,~.~_..,_____,__".. _~h·__._·_."__·__· ..____ ,..__,._._._______ ~____..._ __~...".._ ."',.,~_'_..,,"~.._ .'_,_ .".. ""'_"'...., ._".h."..".... '. ..........." _.,,"_..._...... '.."'''.__.___..., ....,....__......... ._....__ ..m'~ __~. _."".__._. .,,_..._..,,_ Falls Creek 1/1RD E,i,l..ittg"",. ""Jì"e,e.".""....£.C),.r,....".,,':£? e-¡;,mit." ."...."tQ..""...D.~",;L.l..l....".... .~:t~~:~I· ['~~I:\ ::t¡t]:t .I~r"-; f~" ill-JIIIII NON-REPORTING 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT NON-EMPLOYEE COMPo PRIZES, AWARDS, OR DAMAGES - - -- _ f~':4 ':l~Y~::t :.1.1 ~LIJ ~T/I:J::t: I!wwl:I&I ...p?œil~ .,:I:(o[.IIIJ"II:I~: ....... ~~ì:'\ COPERATOR · :{'''I..':t.''I.",.~l, ITV STATE A.F.E. 1 ACCT. CODE OR ------- Marathon Oil Company P.O. Box 196168 ANCHORAGE ALASKA99519-6168 _I ~ ~Tlt1t.Iit::l ~ LIJI'jI :J ::t:1 ul 00 . 5 ~ ~ III I: ¡. 2 5 2 0 0 OS? I: 0 ¡. III 0 ? a 5 b ~ III VIEW ': Pay: VOID AFTER 180 DAYS ",,",:.:,".~~:~,.-.::::-:..,,,> :~.:::" ,"./.,:':,'" ".:''-:.,<':: ..<". .~''-', .x, ",/'.,./ "".' "J~~: A~~T'~~ ~e~R~:~t,J~T¥AWH,1~E ~,M9U~~1)N.~" ::/": ,~./:,,::'.}' ,.)'''.~(' J:'~.{:,~.;::':'.:/'.:'.~~':'::/ .:/:'/':' :::::.: :::;:~::::.~:: ,.::~?~;::,~~~~:~~~;:, ,~~':·".99!?~.::"~::~/~7j~T~~~~77~7:~7~~~:~~j,7:·:..:··:::-::.~~::.fj·~.:···~:::·:,;:7~:7:·:::,··":7 :::::·:·~:·;~·~F;~!~~',;;~~::::;~9Þ~~~; .': Marathon Oil Company . NATIONAL BANK OF ALASKA ¡'V/J /J ' ' .'. . ANCHORAGE ALASKA f3Y-~~__.,,_______.:..-.__~ , AUTHORIZED SIGNATURE i: 1::1 :J~t~ ~1!lïI.: I ~-. .ItIIIIJITjl::t ~~It{¡]~' f~' I ~ ~~, :f.I~W~".::I :~M~':~ ~4 :rt]. ..-wr~' ~ .~'~r~.._ ...... . . "" ,. ...... -.... . . -.... . :'!). ..~.', .' .... , 01534 Jo/2ö?/~ MATCH AMOUNT IN WORDS WITH NUMBERS .. ... . -.. ... .... ..' '.. ." .."."" .' .. .' .~' :" ,,:" .::',,,',,.:', .... .." :.. .:" ;:' .::.. .,' ." .~ ::·1:0~J:~.~,lQ/.:::?:·;.:/ .:::::'/.:: :.;::-: .:i/.::/ ..('. .... Alaska. Oil . &, Gas Conunission 3~3 ·West· 7th Ave, ·Suite 100 -_. Ancþo:rage~. .AK." ..99501 ., .. . ..' '" . . .' '.. ." . ..' . .' .. . '.' . '. " ..' '" .-"... '.' ...' . .' " FORM 3...?0.2 REV. 4/97 . ~'Y '''~~, :~~~ :9:r~r..,~f.::,.. ." . .' . ".. '. 5; 1252 Marathon Oil Comcany ANCHORAGE ALASKA THIS DOCUMENT IS VOID IF RED COLOR BACKGROUND IS ABSENT (~ ¡,' ) ) CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL " ) ) , TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ \ $~\¿ ~\,. Q $ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last· two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DI~. R DI OSAL WNO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be . clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (name on permit). Annular disposal has not been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved'subject to full complian with 20 AAC 25.055. Approval to peñorate and produc s ontingent upon issuance of a conservation order approvi a spacing exception. (Companv Name will assume the liability of any protest to the spacing except n that may occur. ""~'i '0 ~ ~!15 ereek- WELL PERMIT CHECKLIST COMPANY IL (Ct-~..¡I(fYP\ WELL NAME # / R D PROGRAM: exp _ dev 2- redrll ~ selV _ well bore seg _ann. disposal para req _ FIELD & POOL .7 ef(') 5C(-) INIT CLASS DP_V' f 0M GEOL AREA BZD UNIT# D~ I Õ ON/OFF SHORE (:1/.., ADMINISTRATION 1. Pennitfeeattached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . . ) N 3. Unique well name and number... . . . . . . . . . . . . . . . YY:)~N rðlb CÎ-GJ. :&::- Óq~ pc-of f~ iAr1de....f,~<t..e.J..· _. _ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 1 _ ~ , 5. Well located proper distance from drilling unit boundary. ~. . Y ,_'iA< ...."),PO....c...1 Ÿ1~ ~.L c e eh'"r1-- Kq f..) i M .~ r- ?-D /f,;:}( Z~, OS::; :3' 6. Well located proper distance from other wells.. . . . . . ~ -¡jd6' iU-e.!t U 11e..5 fA) ¡:-It. i k- -!-tUL. Ü~(~ dre..eL L(/t/'-I. '':ïJ'fL -to 1:- d- 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N. tp !exJuc.+7f ~ f M. kr UC¿/ 0- Vl J.f¿ 0.. / cl~1 / Ie.- }O (-f-tV'11 / /~) / 8. If deviated, is wellbore plat induded.. . . . . . . . . . . .. . y) J.Fe..e-1 at --IIuL-- boµ~"" Gt 6.e tue-eJ? ~ A-It:? Cre-e/:;, {t..H~"¡- 9. Operator only affected party.~ . . . . . . . . . . . . . . . . N ¡/lei --IIu.. /1.1.. r:.J; ~ ~k ~_p_ /P4S'¿ ?1-:J ..fl"-..e ....:::3o¿i-#utJi> . 10. Operator has appropriate bond in force. . . . . .....L:::. . . . . . IA-e. tvU¿ tUi2.;1 ÒJ2- dr:iIILd/ b(-l../' IT /ffl~.D-f k *-5-I-ed 11. Pennit can be issued without conselVation order.~. . . . . . Dr¡<:prodvcz¿f-1 u n-I-; ( &L ~4C111 '1 u2-XC' -. frY\. I'LQ.~ /-Y¿¿),-- AP~/. DATE 12. péññit can·be issued without administrative approval.. . . . . . 3rtLiÃ..j..¿.d. Y -.......) X /) 7Z7-0 I 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N / ENGINEERING 14. Conductor string provided .. . . . . . . .. . . . . . . . . . Y N ~ ~ \ \.\- \ \ 15. Surface casing protects all known USDWs. . ., . . . . . . . Y N ~\¿;<L:t\OC...-¥- 'Q e..'f... '\ s.. '\ \. ~ ~<c..\ 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . Y N - ::::- \ l 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . Y N ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . NN (U. \ ~~\ ~ '""' ~ 1"'\~ \Q:... SR-,.,.:)<t.. V'- . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations . . . . . . . . . . ~ \..J ~ 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N 25. 80PEs, do they meet regulation . . . . . . . . . . . . . . . . Y N ~ ~~~r DATE 26. BOPE press rating appropriate; test to ~t::>()Õ psig. . NN \-'j:>.. <:.,,\' c.<'-\'\'"'-"'4>~ ~ ~c..~~l l,¿ff"(f Þ "\ (f) ~-()\ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . y' N . 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . y~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. Y N / 31. Data presented on potential overpressure zones . . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . .~. . ... . Y N APP-R DATE.. I 33. Seabed condition survey (if off-shore). . . . . . . . . .. .' Y N ;:tÞ -¡. z1·C1 34. Contact name/phone for weekly progress reports f ratory only] Y N , ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. " ~~~œ; . (C) will not impair mechanical h,tegrity ,of 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 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~Þ&f~ -' ~~ ., WM ~ 'R~S ~T'ËM/~111 ~b,,-() \ JMH c o z o -I ~ :::0 -I m (' APPR DATE Y N Y N 6..\ "7'-<- ( ~--.)\~~"><:,. ~Sû'-,-,,=>e\\ . ~ ----- Z -I :r: en :Þ :::0 m » \ GEOLOGY /' ~ Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) A~ DATE &- í-~7-D( ENGINEERING 'f ~ APPR DATE ~J ~ ~/;}-S- GEOLOGY APPR DATE Á.// ~~ / ~ IJ PROGRAM: exp _ dev X- redrll ~ serv _ well bore seg _ann. disposal para req _ GEOL AREA <¿:-...> .t"'f UNIT# Á1 A. ON/OFF SHORE ~" ) c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~" ,r ¡1 y . 14t? þ/~~ :¡1JJ~Þw-fí:~ ~ /1~ , ~UJ /~~ :;I" ~~. #!¿ fi~~ ~4~ ~ ~M Ä_~n ,¿ . ~N /_~=...;::..... :i{,.. £d{ ~ 4uf ~~ ~ f -!l-"9~ç-~./ ~...~~'" 7¿,.r- ~ / V'~ ~~ ~ .#---~j ~/s.£:-~~. . L 1/ /¿/ N *' tJt..¡{ ~.n~.f- #.51c.c( '7"~dlU~ p1'/~/~/",Il!tJ/y, ~~~ Y N ~~n ~/5S/~ ~ tí/ a¿~r1?/r14 ~ ~1 ~ fp U~ J4 a $f'~£:~ ~Ä ~ ~.:-, .~ Y ~) . $ ~ ~~,~\,,~ç~~1 ...."> ~~~~c\ ~N ~~::~ ~\\~~~~~()~~\ V&; . Y N Y N··/' 'l 4/ /.} \ N ' N c 0 Z 0 -I :E :::u -I' m - z -I ::E: .. en )- ( :::u m » WELL PERMIT CHECKLIST COMPANY ~ .r..,.~~ WELL NAME FIELD & POOL À/. A r - INIT CLASS ./)rlJ./ 1/ ....(' ADMINISTRATION 1. Pennitfee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available'in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . ... . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Pennit can be issued without conservation order. . . . . . . . 12. Pennit can·be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided . . . . . . . . .. . . . . . . . . . 15. Suñace casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . .'; . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reseNe pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling ,fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation . . . . . . . . . . ~ . . . . 26. BOPE press rating appropriate; test to ~{:)t)t J psig. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . 30. Pennit can be issued w/o hydrogen sulfide measures. . . . ,. 31. Data presented on potential overpressure zones . . . . . . . 32. Seismic analysis of shallow gas zones. . . . . '. . . . . . . . A..grR .P,.t~~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . If?~ J'>f/A/ 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . '. . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; , (C) will not impair mechanical integrity ,of 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: , ~ÞB k, .. ~~W . W~ -8~s Loí - ~t þ-.s¡ø~ ~ ~)«. T'Ë~~1"YVZ" I~< JMR . ~ f'<!v:-'\~t.'è) ~ {~'ì û.\\ ~~~~ ,,~~\~ Y N Y N Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim'plify finding infonnation, infomlation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chmnologically organize this category of information. <:9.0/-/55 ~ EPOC~H ( CONFIDENTIAL Craig Silva - Sr. Logging Geologist Ralph Winkleman - Sr. Logging Geologist August 14, 2001 Kenai Peninsula, Alaska ( Section 6- T1 N-R12~ SM FALLS CREEK UNIT FALLS CREEK UNIT #1 RD MARA THaN OIL COMPANY ( ( . (' ( ( ~ ' ~Marathon Oil Company - Falls Creek Unit #1 RD ( WELL RESUME {O,.y.-9~ . MARATHON OIL COMPANY '[¡"4( WELL NAME: FALLS CREEK UNIT #1 FIELD: FALLS CREEK REGION: KENAI PENINSULA, ALASKA LOCATION: 1898'FSL,2885'FEL SEC 6-T1N-R12W SM BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 291.77' AMSL GL: 265.80' AMSL API NUMBER: #50-133-10005-01 OPERATOR: MARATHON OIL COMPANY ( Operator Representatives: JERRY LORENZEN, ROWLAND LAWSON Company Geologist: DAVID BRIMBERRY CONTRACTOR: INLET DRILLING DRILLING RIG: GLACIER DRILLING #1 T oolpusher: GEORGE BREWSTER, MIKE LESLIE MUDLOGGING COMPANY: EPOCH WELL SERVICES, INC. LogQing Geologists: CRAIG SILVA. RALPH WINKELMAN MUD COMPANY: MI Mud Engineers: ROD MABEUS, BOB WILLIAMS, E.D. BUTTS MWD COMPANY: BAKER HUGHES INTEQ MWD Engineer: STEVE STURGEON; MIKE REIL Y DIRECTIONAL COMPANY: BAKER HUGHES INTEQ Directional Driller: A. J. HARSTAD ( CEMENT COMPANY: BJ SERVICES '- U EPOCH 3 ( ( (!!)Marathon Oil Company - Falls Creek Unit #1 RD ( WIRELINE COMPANY: Logging Engineer: SCHLUMBERGER RAHMI U. KEMALAWATI ( ( fJ EPOCH 4 ( ( (' (M.)Marathon Oil Company - Falls Creek Unit #1 RD {Ò~f)b~ 7'ft DRilliNG SUMMARY PROSPECTUS The objective of Marathon's Falls Creek Unit #1 RD well was to drill a producing gas well in the Tyonek Formation. The surface location was a new pad built over the old original Falls Creek Unit. The original Falls Creek well was drilled in 1960-1,961, and had never been brought on production. The well was a step out drilled directionally to the West-Northwest. BRIEF REVIEW OF ACTIVITY The drilling rig was Marathon's Glacier Drilling Rig #1. An 8 %" window was cut in the original hole's 9 5/8" casing at 3094', and the well was officially spudded on July 31, 2001. Total Depth of 8900' (8327'TVD) was reached on August 14, 2001. 8 %" hole was milled from 3094' to 3134' MD, and then 6 3/4" hole drilled from 3134' to Total Depth. There were no significant problems encountered during the drilling, logging and completion phases of this well. BRIEF DIRECTIONAL REVIEW ( At kickoff, Falls Creek Unit #1 RD was an inclination of 16.94° and an azimuth of 2700. Hole Inclination Angle was built to a maximum of 44.50° at 3,985' MD / 8,013.14' TVD before being directed toward vertical as per the well plan, and eventually reaching 0.40° at 8464' MD / '7891.15' TVD and finishing at a projected 2.3° at 8,900' MD /8,327' TVD. The well path was started directly to the west at Azimuth 270°, moved slightly northwest to Azimuth 280° while angle was being built, and then redirected to Azimuth 270° - 268° during the approach to vertical. LOGGING PROCEDURES Epoch Well Services provided RIGWA TCH 2000™ Drilling Monitoring services and DML TM Mudlogging Service. Hydrogen flame ionization total gas and chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by an air motor driven gas trap located at the shale shaker header box and extractéd continuously from the trap to the unit by sample pumps. The gas trap was cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated regularly. Cuttings samples were collected at regular 10' - 20' intervals as directed by Marathon's sampling program. ( [1 EPOC~H 5 ( ( (M)Marathon Oil Company - Falls Creek Unit #1 RD (- DAILY CHRONOLOGY Lc:iiYl1b4'l'lt 7/31/2001: Cut window from 3095' - 3130'.Drill new hole 3130' - 3134'( Top of window @ 3094', bottom of window @ 3110'.24' new hole). Pump sweep and circulate well clean. Pull mill assembly into casing. Clean mud pits. Mix 500 barrels new mud. 8/01/2001: Finish mixing new mud. Displace well to new mud. Circulate and condition mud. Pre job safety meeting prior to performing leak off test. Rig up cement lines and test BJ unit and lines to 2500 psi. Perform LOT to 15.5 ppg ( 3040' tvd, 1070 psi, 8.7 mw). Rig down BJ. Pump dry job and POOH. Lay down mill assembly, 10 - 6 %" collars, 6 - 5" HWDP. Pick up 6 %" bit and steerable assembly. Pick up 4 %" drilling jars and 3 %" HWDP while RIH. Orient motor above window. RIH and tag @ 3133'. Pull BHA above window and change swab #1 in pump #1. RIH and clean 3133' to 3134'. Directional drill and survey 3134' - 3307'. Hydraulic hose between hydraulic pump and hydraulic motor on mud pump #2 ruptured. Pull bit and BHA into casing. Change hose and trouble shoot mud pump #2. ( 8/02/2001 RIH to 3120' and CBU, twice with mud pump #2. Continue to trouble shoot mud pump #2 (Crank shaft locked up). Rig up BJ cementing unit. Change liners in pump #1 from 4.5" to 5". Clean oil from pump room floor. Filter new oil and fill hydraulic reservoir. RIH to 3130'. Test BJ unit and record slow pump rate. RIH to 3307'. Directional drill and survey 3307' - 3501'. 8/03/2001: Continue directional drill and survey 3501' - 3542'. CBU twice with BJ unit at 325 gpm with 70 rpm. Directional drill and survey 3542' - 3979'. CBU with rig pump. CBU with BJ unit @ 325 ,gpm and 70 rpm. POOH to 3130'. CBU with BJ unit @ 325 gpm and 0 rpm. Mix and pump dry job. POOH. Change out bit. RIH with BHA. Directional drill 3979' - 4070'. 8/04/2001: Directional drill 4070' - 4296' CBU with rig pump @ 245 gpm, 70 rpm. CBU twice with BJ unit @ 328 gpm, 70 rpm. Directional drill and survey 4296' - 4610'. CBU with rig pump @ 245gpm, 70 rpm. CBU twice with BJ unit @ 323 gpm, 70 rpm. POOH to 3130'. CBU with BJ unit @ 323 gpm. Service rig. Inspect derrick. Change out #2 shaker screens. RIH. 8/05/2001: Directional drill 4610' - 4923'. (Lost rig power due to generator #2 failure 01 :00 to 01 :30.) CBU with rig pump @ 245 gpm , 70 rpm. CBU twice with BJ unit @ 328 gpm, 70 rpm. POOH to 3173'. Slug pipe and POOH. Trouble shoot #2 generator (Can not repair without new parts). Change out bit and RIH with BHA. Test motor and MWD. RIH to 3106'. Service rig. Continue to RIH. Directional drill and survey 4923' - 5102'. 8/06/2001: Continue to drill 5102' - 5240'. CBU with rig pump @ 245 gpm, 70 rpm. ( CBU with BJ unit @ 328 gpm, 70 rpm. Change out shaker screens. Directional drill and ~EPO(:H 6 (' ( (!!)Marathon Oil Company - Falls Creek Unit #1 RD ( survey 5240' - 5365'. CBU with rig pump @ 245 gpm, 70 rpm. CBU twice with BJ unit @ 328 gpm, 70 rpm. Directional drill and survey 5365' - 5675'. CBU with rig pump @ 245 gpm, 70 rpm. CBU twice with BJ unit @ 328 gpm, 70 rpm. 8/07/2001: Finish CBU. POOH wet to 4763'. Pump dry job and continue to POOH. Test BOP's Annular tested to 250 - 3000#, all other 250 - 5000#. Witness waived by Chuck Cheevy (AODCC). Make up BHA. RIH to 3100'. Slip and cut drill line. Inspect and adjust brakes. RIH. Directional drill and survey 5675' - 5900'. 8/08/2001: Directional drill and survey 5900' - 6520' . 8/09/2001: Directional drill and survey 6520' - 6698'. CBU. Pump pill. POOH. Service rig. Repair pillow block brahe link. Change battery in MWD. Pick up bit #7. RIH with BHA. Surface test MWD. RIH. Directional drill and survey 6698' - 6741'. Circulate and work pipe while installing gear end on pump #2. Directional drill and survey 6741' - 6803'. . 8/10/2001: Directional drill and survey 6803' - 6830'. Circulate at reduced rate and work pipe while working on pump #2. Directional drill and survey 6830' - 7263'. 8/11/2001: Directional drill and survey 7263' - 7494'. CBU. POOH 15 stand short trip to 6550'. RIH. Directional drill and survey 7494' - 7692'. ( 8/12/2001: Directional drill and survey 7692' -7815'. CBU. Pump dry job. POOH. Change liners in pump #1 from 5" to 4.5". Change out bit and motor. Pick up 11 joints HWDP. RIH with BHA. Surface test MWD. RIH. Directional drill and survey 7815'- 7949' . 8/13/2001: Directional drill and survey 7949' - 8638'. 8/14/2001: Directional drill and survey 8638' - 8900', TO. Circulate bootoms up . Pump hi vis sweep. Pump dry job. POOH to window. Service rig. RIH. Circulate bottoms up. Pump hi vis sweep. Pump dry job. POOH. 8/15/2001: Continue to POOH. Lay down MWD and motor. Hold pre job safety meeting for wireline operations. Rig up Schlumberger. Run wireline logs. Rig down Schlumberger. Pull wear ring. Rig up and test BOPE. 8/16/2001: Continue test of BOPE. Install wear bushing. Make up BHA. RIH to 8900'. CBU. Pump 46bbl sweep. Drop Gyro surveying tool and pump to bottom. Pump dry job. POOH laying down drill pipe and BHA. Survey at 93' intervals. Lay down drill pipe from derrick. Clear rig floor and prepare to to run 4 %" casing. 8/17/2001: Install 4 %" buttress crossover on floor safety valve. Change rams from 4" to 4 %". Change out bails and elevators. RIH with 4 %" (12.6 Ib/tt) buttress casing. Fill ( pipe and circulate at 3110'. Continue RIH with casing. Land casing in hanger. (Note (;I EPO(~H 7 ( ( ( ( l ~. ( ~Marathon Oil Company - Falls Creek Unit #1 RD chemical injection mandrel at 1950', float collar at 8849', and shoe at 8894'). Begin rigging up BJ cementers. Rig up cement head and circulate. Condition hole. Hold PJSM for cementing procedures. Load head. Test lines to 3000psi. Pump spacer (40bbls, gO/oKCL), lead slurry (150bbls, 12.5ppg, 405 sacks class "GJI cement) and tail slurry (130bbls, 15.7ppg, 647sacks). Drop plug. Displace (134.5bbls, 4%KCL). Bump plug. Hold at 3000psi. 8/18/2001: Rig down BJ cementers. Start rigging down mudlogging services. Pump cellar. Clean out BOP's. Run lock downs in. Rig down rig floor. Clean pits. Haul out trash and dog house. Clean trip tank. Remove cylinder covers on all rams. Remove traps. Rig down BOP's. Epoch Unit # 6 released ~EPOCH 8 ( ( ( 'I l ( (!!)Marathon Oil Company - Falls Creek Unit #1 RD l UNFI/)¡:JI 'lf1l41. LITHOLOGY SUMMARY SAND (3105'·3230') = MEDIUM GRAY TO DARK GRAY; FINE UPPER TO COARSE LOWER; MODERATELY WELL SORTED IN MEDIUM RANGE; ANGULAR TO SUBANGULAR; DISAGREGATED; IN PART VERY LOOSELY CONSOLIDATED WITH CLAYEY SUPPORTING MATRIX; MODERATE TO STRONGLY CALCAREOUS; ABUNDANT DARK GRAY TO GRAYISH BLACK LITHIC CLASTS. TUFFACEOUS CLAYSTONE (3170' ·3250') = LIGHT GRAY WITH OCCASIONAL LIGHT BROWN SECONDARY HUES; VERY SOFT; VERY STICKY; CLAYEY TO SILTY TEXTURE; DULL TO EARTHY LUSTRE; FAIR TO GOOD COHESIVENESS; FAIR ADHESIVENESS; HYDROPHILIC; SLIGHTLY SOLUBLE; MODERATE TO STRONGLY CALCAREOUS; COMMON TO ABUNDANT BLACK CARBONACEOUS MATERIAL; TRACE THIN COAL STRINGERS. ARGILLACEOUS CLAYSTONE (3105'·3300') = MEDIUM GRAY, COMMON LIGHTER OR DARKER GRAY VARIATIONS; SOFT TO BRITTLE, MOSTLY SLIGHTLY FIRM TO SLIGHTLY BRITTLE; OFTEN SHALEY IN PART, CLOSELY GRADATIONAL TO SHALE; COMMON TO ABUNDANT VERY THIN CARBONACEOUS LAMINATIONS, ALSO GRADES TO CARBONACEOUS SHALE; CLAYEY TEXTURE; DULL TO MODERATELY EARTHY LUSTRE; SOME BRITTLE SILTIER PIECES ARE CALCAREOUS. SILTSTONE (3250'·3350') = MEDIUM GRAY TO MEDIUM LIGHT GRAY; BRITTLE AND TOUGH, TO SLIGHTLY BRITTLE AND FRAGILE, TO SOFT; MOSTLY ARENACEOUS, BUT ALSO GRADING TO CLAYSTONE; SILTY TO CLAYEY TO MINOR ABRASIVE TEXTURE; DULL TO EARTHY LUSTRE; OFTEN SLIGHTLY CALCAREOUS, SPOTTY VERY CALCAREOUS PIECES GRADING TO CALCAREOUS TUFF; SCATTERED BLACK, MICROTHIN, CARBONACEOUS LAMINATIONS AND PIECES THROUGHOUT. SAND (3290'-3390') = MEDIUM TO DARK GRAY OVERALL APPEARANCE; FINE LOWER TO COARSE LOWER; MODERATE TO MODERATELY WELL SORTED IN FINE UPPER TO MEDIUM LOWER, LOCALLY POOR SORTING; DISAGGREGATED WITH SPOTTY FRAGMENTS OF CONSOLIDATED CALCITE CEMENTED SANDSTONE; ANGULAR TO SUBANGULAR, DISCOIDAL-SUBDISCOIDAL; LITHIC ARENITE TO COMPOSITIONAL GRAYWACKE(>30%LITHICS); ABUNDANT METALITHICS AND MAFIC MINERALS ARE BLACK TO DARK GRAY, LIGHT GREENISH GRAY, BROWNISH GRAY TO YELLOWISH BROWN. TUFFACEOUS CLAYSTONE (3250'·3450') = LIGHT GRAY; LIGHT BROWNISH GRAY SECONDARY HUES; SOFT; CLAYEY TO ASHY TEXTURE; DULL TO "SOFT" GLASSY TO EARTHY LUSTRE; MODERATE TO GOOD ADHESIVENESS; POOR COHESIVENESS; COMMON VISIBLE SHARDS. [:I EPOCH 9 ( r , ( (M'>Marathon Oil Company - Falls Creek Unit #1 RD SANDSTONE/SAND (3390'-3540') = MEDIUM TO MEDIUM DARK GRAY; FINE LOWER TO VERY VERY COARSE LOWER; MODERATE TO POOR SORTING OVERALL; LOCAL ZONES MODERATELY WELL SORTED IN MEDIUM RANGE; ANGULAR TO SUBANGULAR, SUBDISCOIDAL TO DISCOIDAL; MOSTLY DISAGGREGATED, WITH LOCALLY ABUNDANT CALCITE CEMENTED CONSOLIDATED SANDSTONE PIECES; CONSOLIDATED SANDSTONE IS FINER THAN LOOSE SAND GRAINS, AND OFTEN SUPPORTED BY MIX OF SILT AND CALCITE; LITHIC ARENITE TO COMPOSITIONAL GRAYWACKE (>300/0LITHICS); ABUNDANT DARK GRAY ARGILLITE-PHYLLITE DERIVED LITHICS; COM BLACK MAFICS; SPOTTY TO LOCALLY COMMON GREENISH GRAY GREENSTONE LITHICS; COMMON LITHIC COAL-CARBANACEOUS GRAINS. SANDSTONE/SAND (35401-36601) = NOTE SUBTLE OVERALL COLOR CHANGE FROM MEDIUM DARK GRAY WITH NO SECONDARY COLORS TO MEDIUM DARK GRAY WITH STRONG GREENISH GRAY SECONDARY HUES; MEDIUM UPPER TO COARSE UPPER AND MODERATE TO MODERATELY WELL SORTED; SUBANGULAR TO ANGULAR; DISCOIDAL TO SUBDISCOIDAL, BUT NOTE INCREASED (SUB)SPHERICAL GRAINS; ROUGHLY EQUAL FRACTIONS OF DISAGGREGATED SAND AND CONSOLIDATED SANDSTONE; CONSOLIDATED PIECES ARE ABUNDANTLY CALCITE CEMENTED, MOSTLY GRAIN SUPPORTED AND OFTEN MODERATELY HARD AND TOUGH RATHER THAN FRIABLE; COMPOSITIONAL GRAYWACKE(>30%LITHICS) TO LITHIC ARENITE; ESTIMATE 40-600/0 QUARTZ, 5-150/0 COLORLESS AND TRANSPARENT AMORPHOUS (VOLCANIC) GLASS, TRACE-5% FELDSPAR, TRACE-50/0 CHERT, 25-500/0 LITHICS; QUARTZ IS PALE GRAY TO COLORLESS TO PALE BROWN, AND DOMINANTLY TRANSLUCENT; LITHICS ARE ROUGHLY EQUAL FRACTIONS OF DARK GRAY TO BLACK MAFIC MINERALS PLUS ARGILLITE-PHYLLITE META FRAGMENTS, AND VARIOUS GREEN TO GREENISH GRAY GREENSTONE ROCK FRAGMENTS; TRACE RED JASPER FRAGMENTS. ARGILLACEOUS CLAYSTONE (3300'-3800') = MEDIUM GRAY, COMMON LIGHTER OR DARKER GRAY VARIATIONS; SOFT TO BRITTLE, MOSTLY SLIGHTLY FIRM TO SLIGHTLY BRITTLE; OFTEN SHALEY IN PART, CLOSELY GRADATIONAL TO SHALE; COMMON TO ABUNDANT VERY THIN CARBONACEOUS LAMINATIONS, LOCALLY GRADES TO CARBONACEOUS SHALE; CLAYEY TEXTURE; DULL TO MODERATELY EARTHY LUSTRE; VERY COMMON CALCAREOUS PIECES GRADE TO CALCAREOUS TUFF. SILTSTONE (3350'-3750') = MEDIUM GRAY TO MEDIUM LIGHT GRAY; BRITTLE AND TOUGH, TO SLIGHTLY BRITTLE AND FRAGILE, TO SOFT; BOTH ARENACEOUS AND CLAYEY IN PART; SILTY TO CLAYEY TO ABRASIVE TO ASHY TEXT; SOME GRADE TO CALCAREOUS TUFF AND TUFFACEOUS SILTSTONE. SANDI SANDSTONE ( 3760' - 38801)= MEDIUM TO DARK GRAY WITH "SALT AND PEPPER" APPEARANCE; FINE UPPER TO COARSE LOWER,DOMINANTL Y ( MEDIUM GRAIN; ANGULAR TO SUBANGULAR; MODERATE TO GOOD SORTING; ( (, ~ EPO(~H 10 ( I (Ü\ (, ~Marathon Oil Company - Falls Creek Unit #1 RD DOMINANTLY DISAGGREGATED WITH SCATTERED CONSOLIDATE PIECES;VERY HARD WITH VERY CALCITIC CEMENT; DOMINANTLY QUARTZ (60 - 70°/0) ABUNDANT DARK GRAY TO BLACK METALITHICS AND MAFIC MINERALS; SCATTERED TO COMMON LITHIC COAL AND CARBONACEOUS CLASTS; OCCASIONAL VERY LIGHT GRAY, ASHY SUPPORTING MATRIX. TUFFACEOUS CLAYSTONE (38501 - 39501) = LIGHT TO LIGHT MEDIUM GRAY WITH LIGHT BROWN TO LIGHT BROWNISH GRAY SECONDARY HUES; VERY SOFT; VERY STICKY; CLUMPY, AMORPHOUS, GLOBULAR CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY, OCCASIONAL MICROSPARKL Y LUSTRE; HYDROPHILIC; EXPANSIVE; GOOD ADHESIVENESS; POOR TO FAIR COHESIVENESS; SLIGHT TO MODERATELY CALCAREOUS; COMMON BLACK, MICROTHIN, CARBONACEOUS LAMINATIONS; ABUNDANT COAL/ CARBONACEOUS MATERIAL CLASTS; TRACE CREAMY WHITE TO LIGHT GRAY TUFF. COAU CARBONACEOUS SHALE ( 39051-39801)= BLACK WITH DARK DUSKY BROWN SECONDARY HUES; MODERATELY HARD; BRITTLE AT TIMES; BLOCKY TO SUBBLOCKY; DOMINANTLY PLANAR FRACTURE WITH RARE CONCHOIDAL; SMOOTH TO SLIGHTLY GRITTY TEXTURE; EARTHY TO MATTE LUSTRE;HARD, BLACK COALS GRADING TO DARK BROWN SHALE; LIGNITIC IN PART;TRACE VISIBLE OUTGASSING BUBBLES ON HARDER COALS. ( SAND I SANDSTONE (39001-41201) = OVERALL MEDIUM DARK GRAY TO MEDIUM GRAY WITH GREENISH GRAY SECONDARY HUES; FINE UPPER TO VERY COARSE LOWER; MODERATELY POOR TO LOCAL MODERATELY WELL SORTED; ANGULAR TO SUBANGULAR, SUBDISCOIDAL TO DISCOIDAL; TOPS OF MORE MASSIVE SANDS HAVE COMMON (SUB)SPHERICAL GRAINS; MOSTLY DISAGGREGATED WITH SPOTTY PIECES OF CONSOLIDATED SANDSTONE; CONSOLIDATED PIECES ARE CALCITE CEMENTED, GRAIN SUPPORTED, AND HARD TO FRIABLE; NOTE MANY LOOSE SAND GRAINS WITH ATTACHED CALCITE CEMENT; LITHIC ARENITE TO COMPOSITIONAL GRAYWACKE(>300/0LITHICS); ESTIMATE 35-550/0 QUARTZ, 5-20°/0 COLORLESS AND TRANSPARENT AMORPHOUS (VOLCANIC) GLASS, TRACE-501o CHERT, TRACE-50/0 FELDSPAR, TRACE DISTINCTIVE RED JASPER; 25-600/0 LITHICS AND MAFIC MINERALS; LITHICS DOMINATED BY DARK GRAY ARGILLITE-PHYLLITE ROCK FRAGMENTS, AND BLACK MAFIC MINERALS, WITH TRACE TO SPOTTY GREENISH GRAY TO VARI-GREEN GREENSTONE ROCK FRAGMENTS; SPOTTY VERY LIGHTLY FROSTED QUARTZ GRAINS; TRACE TO SPOTTY SUBHEDRAL COLORLESS TO VERY PALE GRAY TRANSLUCENT QUARTZ GRAINS; COMMON CLASTIC COAL/CARBONACEOUS SHALE LITHICS; TRACE OF DISTINCITIVE TRANSPARENT BLUISH GREEN AMORPHOUS VOLCANIC GLASS GRAINS. ( COAUCARBONACEOUS SHALE ( 39801-42801)= BLACK; OCCASIONALLY DARK DUSKY BROWN SECONDARY HUES; BRITTLE TO MODERATELY HARD, TOUGH; ( DOMINANT IRREGULAR TO PLANAR FRACTURE; LOCAL VERY COMMON U EPOCH 11 ( ( ( ( (.M.)Marathon Oil Company - Falls Creek Unit #1 RD CONCHOIDAL; SMOOTH TO DENSE MATTE TEXTURE; DULL TO RESINOUS LUSTRE; GRADING TO BROWNISH BLACK CARBONACEOUS SHALE; LIGNITIC; TRACE OUTGASSING BUBBLES; TRACES OF YELLOW RESINITE. SAND I SANDSTONE (4120'-4290') = MEDIUM DARK GRAY; OCCASIONALLY GREENISH GRAY SECONDARY HUES; FINE UPPER TO VERY COARSE LOWER; MODERATE TO POOR SORTING OVERALL; MODERATELY WELL SORTED IN MEDIUM RANGE; ANGULAR TO SUBANGULAR, SUBDISCOIDAL TO DISCOIDAL; TOPS OF THICKER SANDS HAVE COMMON (SUB)SPHERICAL GRAINS; MOSTLY DISAGGREGATED WITH SPOTTY PIECES OF CONSOLIDATED GRAIN SUPPORTED CALCAREOUS CEMENTED OR HARD CLAY MATRIX SUPPORT; SANDSTONE IS HARD TO FRIABLE; NOTE VERY COMMON SAND GRAINS WITH VISIBLE RIMS OF CALCITE CEMENT; COMPOSITIONAL GRAYWACKE(>30%LITHICS); ESTIMATE 30-50% QTZ, 10-150/0 COLORLESS TRANSPARENT (VOLCANIC) GLASS, TRACE CHERT, TRACE-S% FELDSPAR, RARE RED JASPER; 30-650/0 LITHICS AND MAFIC MINERALS; VERY AUNDANT DARK GRAY ARGILLlTE- PHYLLITE ROCK FRAGMENTS; VERY COMMON BLACK MAFIC MINERALS; TRACE TO SPOTTY GREENISH GRAY GREENSTONE ROCK FRAGMENTS. TUFFACEOUS CLAYSTONE (4300' - 43801) = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES AND BLACK MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; SOFT TO SLIGHTLY FIRM; STICKY; CLUMPY, GLOBULAR CUTTINGS;ASHY TO CLAYEY TEXTURE DULL EARTHY TO OCCASIONALLY MICROSPARKL Y LUSTRE; FAIR TO GOOD ADHESIVENESS; POOR TO FAIR COHESIVENESS; HYDROPHILIC;EXPANSIVE WHEN HYDRATED; MODERATELY SOLUBLE; NON TO SLIGHTLY CALCAREOUS;TRACE CALCITE' SAND I SANDSTONE (43651 - 4430')= MEDIUM TO DARK GRAY OVERALL WITH SCATTERED WHITE AND TRANSLUCENT TO CLEAR QUARTZ GRAINS; VERY FINE UPPER TO COARSE LOWER, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; POOR TO MODERATE SORTING; DOMINANTLY DISAGGREGATED WITH SCATTERED VERY FINE GRAIN, CALCAREOUS CEMENTED, HARD SANDSTONE; ABUNDANT BLACK MAFIC MINERALS; RARE EMERALD GREEN LlTHS COMMON BLACK CARBONACEOUS MATERIAL.' COAL I CARBONACEOUS SHALE (43801-4500')= BLACK WITH OCCASIONAL DARK, DUSKY BROWN SECONDARY HUES; HARD TO VERY FIRM, PLIABLE; BRITTLE TO FRAGILE; PLATY TO BLOCKY CUTTINGS;DOMINANTL Y PLANAR FRACTURE WITH SCATTERED CONCHOIDAL AND BIRDEYE FRACTURE SMOOTH TO DENSE MATTE TO OCCASIONALLY GRITTY TEXTURE; DULL TO RESINOUS LUSTRE; GRADING TO CARBONACEOUS SHALE; LIGNITIC; TRACE VISIBLE OUTGASSING BUBBLES. TUFFACEOUS CLAYSTONE (4400' - 4580') = LIGHT TO MEDIUM GRAY WITH ( LIGHT BROWN SECONDARY HUES AND BLACK MICROTHIN CARBONACEOUS U EPOCH 12 ( ( (M)Marathon Oil Company - Falls Creek Unit #1 RD LAMINATIONS AND INCLUSIONS; SOFT TO SLIGHTLY FIRM; STICKY; CLUMPY, GLOBULAR CUTTINGS;ASHY TO CLAYEY TEXTURE DULL EARTHY TO OCCASIONALLY MICROSPARKL Y LUSTRE; FAIR TO GOOD ADHESIVENESS; POOR TO FAIR COHESIVENESS; HYDROPHILIC;EXPANSIVE WHEN HYDRATED; MODERATELY SOLUBLE; NON TO SLIGHTLY CALCAREOUS. SAND (4520' - 4630') = MEDIUM TO DARK GRAY WITH LOCAL "SALT AND PEPPER" APPEARANCE; FINE LOWER TO VERY COARSE UPPER DOMINANTLY MEDIUM UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DOMINANTLY DISAGGREGATED TO LOOSELY CONSOLIDATED WITH VERY LIGHT GRAY TO GRAYISH WHITE, CLAYEY SUPPORTING MATRIX; SCATTERED CALCAREOUS CEMENTED SANDSTONE; HARD; FINE GRAIN; ESTIMATE POOR TO FAIR POROSITY AND PERMEABILITY; COMMON BLACK CARBONACEOUS CLASTICS; LITHIC ARENITE TO COMPOSITIONAL GRAYWACKE(>30%LITHICS); ABUNDANT DARK GRAY TO GRAYISH BLACK MEDIUM GRADE META ARGILLITE- PHYLLITE LITHIC GRAINS; TRACE TO SPOTTY LOW GRADE META GREENISH GRAY GREENSTONE LITHICS. ARGilLACEOUS CLAYSTONE (3800'-4700') = MEDIUM GRAY, COMMON LIGHTER OR DARKER GRAY VARIATIONS; MODERATELY HARD TO SOFT; MOSTLY MODERATELY FIRM TO BRITTLE; COMMONLY SHALEY IN PART, CLOSELY GRADATIONAL TO SHALE; COMMONLY WITH VERY THIN CARBONACEOUS LAMINATIONS; ALSO GRADATIONAL TO CARBONACEOUS SHALE; CLAYEY TEXTURE; DULL TO MODERATELY EARTHY LUSTRE; OCCASIONALLY VERY CALCAREOUS CLAYSTONE GRADING TO CALCAREOUS TUFF. SilTSTONE (3750'-4750') = MEDIUM GRAY TO MEDIUM LIGHT GRAY; BRITTLE AND TOUGH, TO SLIGHTLY BRITTLE AND FRAGILE, TO SOFT; BOTH ARENACEOUS AND CLAYEY IN PART; SIL TV TO CLAYEY TO ABRASIVE TO ASHY TEXT; OCCASIONALLY GRADES TO CALCAREOUS TUFF AND TUFFACEOUS SIL TSTONE. VOLCANIC ASHNERY TUFFACEOUS CLAYSTONE (4710'-4830') = NOTE COMMON "ASHIER" LOOKING TUFFACEOUS CLAYSTONE AFTER 4710'; VERY LIGHT GRAY WITH PATCHY WHITE; SOFT TO SLIGHTLY FIRM; ASHY TO CLAYEY TEXTURE; SLIGHTLY SPARKL Y TO "SOFT" GLASSY LUSTRE TO DULL LUSTRE; ABUNDANT VISIBLE GLASS SHARDS; DE$PITE VARYING DEGREES OF REWORKING, SOME PIECES HAVE A SURFACE TEXTURE THAT APPEARS TO "REPEAT" THE ORIGINAL VITRO- CLASTIC TEXTURE; MOSTLY MASSIVE. COAUCARBONACEOUS SHALE ( 4740'-4900')= BLACK; OCCASIONALLY DARK DUSKY BROWN SECONDARY HUES; BRITTLE TO MODERATELY HARD, TOUGH; DOMINANT IRREGULAR TO PLANAR FRACTURE; LOCAL VERY COMMON CONCHOIDAL; SMOOTH TO DENSE MATTE TEXTURE; DULL TO RESINOUS LUSTRE; GRADING TO BROWNISH BLACK CARBONACEOUS SHALE; LIGNITIC; ( TRACE OUTGASSING BUBBLES; TRACES OF YELLOW RESINITE. ( ( I) EPOCH 13 (' ( ( i" ( ill { (!!.) Marathon Oil Company - Falls Creek Unit #1 RD SAND I SANDSTONE (46301-49201) = MEDIUM DARK GRAY; SPOTTY GREENISH GRAY SECONDARY HUES; FINE UPPER TO VERY COARSE LOWER; MODERATE TO POOR SORTING OVERALL; MODERATELY WELL SORTED IN MEDIUM RANGE; ANGULAR TO SUBANGULAR, SUBDISCOIDAL TO DISCOIDAL; TOPS OF THICKER SANDS HAVE COMMON (SUB)SPHERICAL GRAINS; DISAGGREGATED WITH TRACE PIECES OF CONSOLIDATED GRAIN SUPPORTED CALCAREOUS CEMENTED OR HARD CLAY MATRIX SUPPORT; COMPOSITIONAL GRAYWACKE TO LITHIC ARENITE; ABUNDANT DARK GRAY TO GRAYISH BLACK ARGILLITE- PHYLLITE ROCK FRAGMENTS. SAND I SANDSTONE ( 49201 - 50501) = MEDIUM TO DARK GRAY; FINE UPPER TO VERY COARSE LOWER; MODERATE TO POORLY SORTED OVERALL, BUT DISCERNIBLE FINING UPWARD THROUGH THE THICKEST SAND SECTIONS, AND MODERATELY WELL SORTED IN EACH SUCCESSIVE THIN ZONE; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; DOMINANTLY DISAGGREGATED WITH SCATTERED PIECES OF CALCITE CEMENTED GRAIN SUPPORTED SANDSTONE AND PIECES WITH LIGHT GRAY ASHY/CLAYEY SUPPORTING MATRIX; GENERALLY FRIABLE, BUT OCCASIONALLY HARD TOUGH PIECES; COMPOSITIONAL GRAYWACKE(>30%LITHICS); ESTIMATE 30- 500/0 QUARTZ, 10-150/0 COLORLESS AND TRANSPARENT (AMORPHOUS VOLCANIC) GLASS, TRACE-5°1<> FELDSPAR, TRACE CHERT, 35-60% LITHICS AND MAFIC MINERALS; DOMINANT(85-900/0) LITHICS ARE DARK GRAY TO GRAYISH BLACK MEDIUM META ARGILLITE-PHYLLITE ROCK FRAGMENTS; COMMON COAL/CARBONACEOUS SHALE SAND SIZED CLASTS; MINOR GRAYISH GREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS; QUARTZ IS COLORLESS TO VERY PALE GRAY AND DOMINANTLY TRANSLUCENT; COAUCARBONACEOUS SHALE ( 49001-50501)= BLACK TO VERY DUSKY BROWN; BRITTLE TO MODERATELY HARD AND TOUGH TO VERY FIRM; SMOOTH TO VERY DENSE MATTE TEXTURE; DOMINANTLY IRREGULAR FRACTURE AND BLOCKY HABIT, ABUNDANT BIRDEYE FRACTURE, VERY COMMON CONCHOIDAL FRACTURE; LIGNITE TO NEAR SUBBITUMINOUS; DULL TO OCCCASIONALL Y RESINOUS LUSTRE; SOME PIECES DISPLAY SLOW OUTGASSING BUBBLES; TRACE WITH FRAGMENTS OF YELLOW RESINITE (AMBER). VOLCANIC ASHNERY TUFFACEOUS CLAYSTONE (48301-51801) = VERY LIGHT GRAY WITH PATCHY WHITE; SOFT TO SLIGHTLY FIRM; ASHY TO CLAYEY TEXURE; SLIGHTLY SPARKL Y TO "SOFT" GLASSY LUSTRE; GENERALLY ABUNDANT VISIBLE GLASS SHARDS; DESPITE REWORKING THE ASHY APPEARANCE OFTEN MIMICS THE ORIGINAL VITROCLASTIC TEXTURE. SANDSTONE/SAND (5050-52501) = NOTE SUBTLE OVERALL CHANGE IN SAMPLE AFTER 5200'; SANDSTONE IS VOLCANIC ASHITUFFACEOUS CLAY MATRIX SUPPORTED, AND MATRIX IS A LIGHTER GRAY COLOR THAN IMMEDIATELY ABOVE; FINE UPPER TO COARSE LOWER; NOTE OVERALL DECREASE IN U EPOCH 14 ( ( (.M}Marathon Oil Company - Falls Creek Unit #1 RD (' AVERAGE GRAIN SIZE AND IMPROVED SORTING; MODERATELY WELL SORTED IN MEDIUM RANGE; SUBANGULAR TO ANGULAR, SUBDISCOIDAL TO SUBSPHERICAL; LITHIC ARENITE TO SPOTTY COMPOSITIONAL GRAYWACKE; ESTIMATE 50-65% QUARTZ, 10-15°,10 COLORLESS AND TRANSPARENT VOLCANIC GLASS 20 - 35% DARK GRAY LITHICS AND MAFIC MINERALS. TUFFACEOUS CLAYSTONE (5240' - 5310') = LIGHT TO MEDIUM GRAY, OCCASIONAL DARK GRAY SECONDARY HUES; COMMON BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; IRREGULAR SHAPED CUTTINGS; SOFT TO SLIGHTLY FIRM; CLAYEY TO SILTY TEXTUR DULL TO EARTHY LUSTRE, OCCASIONALLY MICROSPARKL Y; POOR ADHESIVENESS; FAIR TO GOOD COHESIVENESS; COMMON TO ABUNDANT VISIBLE GLASS SHARDS; NON CALCAREOUS; TRACE CALCITE PIECES. COAU CARBONACEOUS SHALE (5330' -5380')= BLACK WITH DARK DUSKY BROWN SECONDARY HUES; FIRM TO MODERATELY HARD; BRITTLE TO FRAGILE AT TIMES; BLOCKY TO PLATY; DOMINANTLY PLANAR FRACTURE WITH SCATTERED BIRDEYE AND CONCHOIDAL FRACTURE; SMOOTH TO SLIGHTLY GRITTY TEXTURE; DULL TO RESINOUS LUSTRE; TRACE VISIBLE OUTGASSING BUBBLES PRESENT; TRACE AMBER. SAND I SANDSTONE ( 5350' - 5430') = MEDIUM TO DARK GRAY WITH SLIGHT "SALT AND PEPPER" APPEARANCE; FINE LOWER TO VERY COARSE UPPER, ( DOMINANTLY MEDIUM; ANGULAR TO SUBANGULAR; POORLY TO MODERATELY SORTED; DOMINANTLY DISAGGREGA TED WITH SCATTERED FRIABLE, CALCAREOUSLY CEMENTED FINE TO VERY FINE SANDSTONE;COMMON LIGHT GRAY, ASHY TO CLAYEY SUPPORTING MATRIX; ESTIMATE POOR TO FAIR POROSITY AND PERMEABILITY. ( TUFFACEOUS CLAYSTONE (5400' - 5510') = LIGHT TO MEDIUM GRAY, OCCASIONAL DARK GRAY SECONDARY HUES; COMMON BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS; IRREGULAR SHAPED CUTTINGS; SOFT TO SLIGHTLY FIRM; CLAYEY TO SIL TV TEXTURE; DULL TO EARTHY LUSTRE, OCCASIONALLY MICROSPARKL Y; POOR ADHESIVENESS; FAIR TO GOOD COHESIVENESS; COMMON TO ABUNDANT VISIBLE GLASS SHARDS; SCATTERED THIN COAL STRINGERS; ABUNDANT SLOUGHING COAL. SANDI SANDSTONE (5470' - 5570')= MEDIUM TO DARK GRAY; VERY FINE TO VERY COARSE LOWER, DOMINANTLY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; POOR TO MODERATE SORTING; DISAGREGGATED TO VERY LOOSELY CONSOLIDATED WITH LIGHT GRAY ASHY TO CLAYEY SUPPORTING MATRIX; SANDSTONE FRIABLE WITH VERY CALCAREOUS CEMENT; SCATTERED VERY COARSE CLEAR TO TRANSPARENT VOLCANIC GLASS; ABUNDANT DARK GRAY LITHICS AND MAFIC MINERALS; ABUNDANT BLACK CARBONACEOUS MATERIALI COAL; TRACE LIGHT GRAY TO LIGHT GRAYISH WHITE TUFFS. ~ EPOCH 15 ( (" (.M)Marathon Oil Company - Falls Creek Unit #1 RD TUFFACEOUS SHALE (5575'-5675') = LIGHT GRAY TO MEDIUM GRAY, WITH TRACE GRAYISH ORANGE PINK SECONDARY HUES; CLAYEY TO ASHY TEXTURE AND MIXED EARTHY TO MICROSPARKL Y LUSTER; HAS A PERVASIVE "GLASSINESS"; MOST IS FIRM TO SLIGHTLY FIRM, BUT ALSO COMMONLY BRITTLE; MODERATE TO POOR FISSILITY OVERALL, WITH RANDOM SEPARATION ALONG CLEAN CLOSE SPACED PARALLEL PLANES; CLOSELY ASSOCIATED WITH TEXTURALLY SIMILAR TUFFACEOUS CLAYSTONE THAT IS MASSIVE AND STRUCTURELESS. TUFFACEOUS SILTSTONE (5575'-5675') = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH PATCHY TO PERVASIVE LIGHT GRAYISH BROWN SECONDARY HUES; FIRM TO BRITTLE; MOSTLY MIXED ASHY TO SILTY TEXTURE; COMBINED EARTHY TO SPARKL Y LUSTRE. SAND / SANDSTONE (5700' - 5800') = NOTE SIGNIFICANT OVERALL COLOR CHANGE FROM DARK GRAY TO LIGHT GRAY; INDIVIDUAL GRAINS ARE TRANSLUCENT LIGHT GRAY, COLORLESS, PALE GREENISH GRAY, BLACK (LITHICS AND MAFICS), AND TRACE RED JASPER; FINE LOWER TO MEDIUM LOWER; MODERATELY WELL TO WELL SORTED IN FINE UPPER RANGE; ANGULAR TO SUBANGULAR, SUBDISCOIDAL TO SUBROUNDED; MANY INDIVIDUAL GRAINS ARE NEARLY SPHERICAL YET HAVE AN ANGULAR "SHARP EDGED" SURFACE; MOSTLY DISAGGREGATED, BUT ALSO COMMON LUMPS OF SOFT TUFFACEOUS CLAY MATRIX SUPPORTED SANDSTONE; SUBLITHIC TO LITHIC ARENITE; ESTIMATE 60-70% QUARTZ PLUS 15-200/0 COLORLESS AND TRANSPARENT (VOLCANIC) GLASS; TRACE-5OJo FELDSPAR, 15-25%> LITHICS; NOTE THAT THOUGH THE LITHICS ARE STILL DOMINATED BY DARK GRAY TO GRAYISH BLACK ARGILLITE- PHYLLITE ROCK FRAGMENTS, OVERALL THE LITHIC GRAINS ARE MUCH MORE DIVERSE, AND THE FRACTION OF GREENISH GRAY TO GRAYISH GREEN TO VARIABLE-GREEN LOW GRADE METAMORPHIC GREENSTONE ROCK FRAGMENTS WAS 10-40% OF THE LITHICS TOTAL. SAND/SANDSTONE (5800'-5870') = MEDIUM LIGHT GRAY TO MEDIUM GRAY; FINE LOWER TO MEDIUM LOWER; GENERALLY WELL SORTED IN FINE UPPER RANGE; ANGULAR TO SUBANGULAR, AND SUBDISCOIDAL TO SUBSPHERICAL; DISGGREGATED; SOFT CONSOLIDATED SANDSTONE WAS TUFFACEOUS CLAY MATRIX SUPPORTED; SUBLITHIC TO LITHIC ARENITE IS GENERALLY THE SAME AS DESCRIBED ABOVE. COAL (5865'·5875') = BLACK; BRITTLE TO MARGINALLY HARD; FRAGILE TO TOUGH; SMOOTH TO VERY DENSE MATTE TEXTURE; RESINOUS TO DULL LUSTRE; SOME APPEARS SUBVITREOUS; BOTH PLANAR AND CONCHOIDAL FRACTURE; LIGNITE; RARE RESINITE (AMBER). TUFFACEOUS CLAYSTONE (5510'·6000') = MEDIUM GRAY TO LIGHT GRAY; COMMON LIGHT BROWNISH GRAY SECONDARY HUES; MOST IS MEDIUM LIGHT ( GRAY, BECOMING MORE GRAYISH BROWN AFTER 5700'; SOFT; SPOTTY TO ( ( [1 EPO(~H 16 ( ( ( ( ( (!!JMarathon Oil Company - Falls Creek Unit #1 RD RARE FIRM OR BRITTLE PIECES; OBVIOUS MATRIX FOR MOST OF THE SAND; ASHY TO CLAYEY TEXTURE; EARTHY TO "SOFT GLASSY" LUSTRE; GRADES TO TUFFACEOUS SILTSTONE. SAND/SANDSTONE/CONGLOMERATIC SAND (5870'-6030') = MEDIUM GRAY WITH FAINT GRAYISH BROWN, GRAYISH ORANGISH PINK AND GREENISH GRAY SECONDARY HUES; GENERALLY IS A COARSER VARIATION OF THE FINE SAND DESCRIBED AT 5800', WITH A MAJOR COARSE TO GRANULE FRACTION; FINE LOWER TO GRANULE; POORLY SORTED; ABUNDANT MEDIUM UPPER TO COARSE UPPER; DIVERSE LITHICS FRACTION WITH GREENSTONE ROCK FRAGMENTS SLIGHTLY DOMINANT; ENTIRE RANGE OF ROUNDEDNESS AND SHAPE; CONSOLIDATED PIECES ARE MIX OF CALCITE GRAIN SUPPORT AND TUFFACEOUS CLAY/SIL T MATRIX SUPPORT. TUFFACEOUS CLAYSTONE (6040' - 6110') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLIGHTLY MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; PRESENT AS SUPPORTING MATRIX FOR SAND; NON TO VERY CALCAREOUS; TRACE CALCITE GRAINS; TRACE BLACK, MICROTHIN CARBONACEOUS LAMINATIONS; TRACE TO COMMON LIGHT GRAY TO WHITISH GRAY ASHY TUFFS. COAL (6100' - 6150') = BLACK WITH DARK DUSKY BROWN SECONDARY HUES ON PIECES GRADING TO CARBONACEOUS SHALE; VERY FIRM TO MODERATELY HARD; BRITTLE AT TIMES; PLATY TO BLOCKY CUTTINGS; DOMINANT PLANAR FRACTURE,TRACE BIRDEYE AND CONCHOIDAL FRACTURE; SMOOTH TO GLASSY TEXTURE;DENSE TO VITREOUS LUSTRE;TRACE YELLOWISH BROWN AMBER ALONG BEDDING PLANES; COMMON VISIBLE OUTGASSING BUBBLES. SAND / SANDSTONE (6130' - 6400')= LIGHT TO MEDIUM GRAY OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY VERY LIGHT GRAY, CLEAR AND LIGHT GREENISH GRAY; SANDSTONE TENDS TO BE LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; VERY FINE UPPER TO MEDIUM LOWER, DOMINANTLY FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; VERY LOOSELY CONSOLIDATED TO MODERATELY WELL, CALCAREOUSLY CEMENTED; HARD TO FRIABLE; SANDSTONE GRADING TO SANDY SILTSTONE AND SILTY SANDSTONE;VERY LIGHT GRAY TO GRAYISH WHITE, ASHY TO CLAYEY SUPPORTING MATRIX; ESTIMATE POOR TO FAIR POROSITY AND PERMEABILITY. TUFFACEOUS CLAYSTONE (6200' - 6310') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLIGHTLY MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; PRESENT AS SUPPORTING MATRIX fJ EPO(~H 17 ( ( { , ( (M)Marathon Oil Company - Falls Creek Unit #1 RD FOR SAND; NON TO VERY CALCAREOUS; TRACE CALCITE GRAINS; SCATTERED LIGHT GRAY TO GRAYISH MOTTLED WHITE ASHY TUFFS. COAL ( 6270' - 6380') = BLACK WITH DARK DUSKY BROWN SECONDARY HUES ON PIECES GRADING TO CARBONACEOUS SHALE; VERY FIRM TO MODERATELY HARD; BRITTLE AT TIMES; PLATY TO BLOCKY CUTTINGS; DOMINANT PLANAR FRACTURE, COMMON BIRDEYE AND CONCHOIDAL FRACTURE; SMOOTH TO GLASSY TEXTURE; DENSE TO VITREOUS LUSTRE;TRACE YELLOWISH BROWN AMBER ALONG BEDDING PLANES; COMMON VISIBLE OUTGASSING BUBBLES. TUFFACEOUS SILTSTONE (5900'-6400') = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH STRONG BROWNISH GRAY SECONDARY HUES, AND PALE BROWN TO PALE YELLOWISH BROWN WITH VARIOUS GRAY AND BROWN SECONDARY HUES; SOFT TO BRITTLE TO FIRM; ASHY TO SILTY TO VARIOUS MATTE TEXTURES; EARTHY TO DIFFUSE GLASSY LUSTRE; SPOTTY TO ABUNDANT VISIBLE GLASS SHARDS AND DEVITRIFIED SHARD FRAGMENTS; GRADES TO TUFFACEOUS CLAYSTONE. SAND/SANDSTONE (6400'-65001) = MEDIUM LIGHT GRAY; GENERALLY HAS A DARK "DIRTY" SALT AND PEPPER APPEARANCE; FINE LOWER TO MEDIUM LOWER; WELL SORTED IN FINE UPPER RANGE; SUBANGULAR TO ANGULAR, SUBDISCOIDAL TO SUBSPHERICAL; MANY INDIVIDUAL GRAINS HAVE A SPHERICAL SHAPE BUT STILL HAVE AN ANGULAR SHARP-EDGED SURFACE; GENERALLY DISGGREGATED, BUT COMMON PIECES OF SOFT TUFFACEOUS CLAYNOLCANIC ASH SUPPORTED SANDSTONE; TRACE TO SPOTTY FRAGMENTS OF (FINE) GRAIN SUPPORTED CALCITE CEMENTED SANDSTONE; NOTE THAT THERE APPEARS TO BE FINING UPWARD THRU THE MASSIVE SAND SECTIONS; SUBLITHIC ARENITE LOCALLY RANGING TO EITHER LITHIC ARENITE OR LITHIC QUARTZ ARENITE; ESTIMATE 65-80°,10 QUARTZ PLUS 10-20°,10 COLORLESS AND TRANSPARENT (VOLCANIC) GLASS, TRACE-50/0 FELDSPAR, 10-25% LITHICS AND MAFIC MINERALS; DARK GRAY TO GRAYISH BLACK ARGILLITE-PHYLLITE ROCK FRAGMENTS DOMINATE (650/0) LITHICS FRACTION WITH MINOR (25%) GRAYISH GREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS, AND MINOR (10%) DIVERSE MIX OF OTHER LITHIC TYPES. TUFFACEOUS CLAYSTONE ( 6310' - 6610') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLIGHTLY MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; PRESENT AS SUPPORTING MATRIX FOR SAND; NON CALCAREOUS; COMMONLY MOTTLED WITH VERY LIGHT GRAY TO WHITE VOLCANIC ASH; GENERALLY VISIBLE GLASS SHARDS; MOST HAS PERVASIVE "SOFT" GLASSY APPEARANCE. TUFFACEOUS SILTSTONE (64001-6700') = MEDIUM LIGHT GRAY TO MEDIUM ( GRAY WITH STRONG BROWNISH GRAY SECONDARY HUES, AND PALE BROWN ( ~ EPOC:H 18 (' ( ( ( ( (, (!!)Marathon Oil Company - Falls Creek Unit #1 RD TO PALE YELLOWISH BROWN WITH VARIOUS GRAY AND BROWN SECONDARY HUES; SOFT TO BRITTLE TO FIRM; ASHY TO SILTY TO VARIOUS MATTE TEXTURES; EARTHY TO DIFFUSE GLASSY LUSTRE; SPOTTY TO ABUNDANT VISIBLE GLASS SHARDS AND DEVITRIFIED SHARD FRAGMENTS; OCCASIONALLY APPEARS SLIGHTLY ABRASIVE; CLOSELY GRADATIONAL TO TUFFACEOUS SHALE AND TUFFACEOUS CLAYSTONE; NOTE ABUNDANT CUTTINGS PIECES WITH VISIBLE MICROTHIN INTERBEDS OF DIFFERENT LITHOLOGIES; NOTE DIVERSE MIX OF ASH DERIVED LITHOLOGIES, WITH BROAD RANGE OF GRAY AND BROWN COLORS AND ASHY TEXTURES. SAND/SANDSTONE (67001-67901) = MEDIUM LIGHT GRAY TO MEDIUM GRAY, WITH STRONG BROWNISH GRAY AND FAINT LIGHT GREENISH GRAY SECONDARY HUES; "DIRTY" PEPPER AND SALT APPEARANCE OVERALL; MORE LITHICS THAN SANDS AT 6400-6700; VERY FINE UPPER TO MEDIUM LOWER; MODERATELY WELL TO WELL SORTED ON FINE RANGE; ANGULAR TO SUBANGULAR; SUBDISCOIDAL TO SUBSPHERICAL; TRACE GRAINS OF GLASS ARE SPHERICAL AND ANGULAR; ALMOST ENTIRELY DISAGGREGATED, SPOTTY LUMPS OF SOFT TUFFACAEOUS CLAY MATRIX SUPPORTED CONSOLIDATED SANDSTONE; TRACE CALCITE CEMENTED GRAIN SUPPORTED; LITHIC ARENITE TO SUBLITHIC ARENITE; ESTIMATE 65-750/0 QUARTZ PLUS 10-200/0 COLORLESS TRANSPARENT (VOLCANIC) GLASS, TRACE-5°J'o FELDSPAR, 15..25% LITHICS PLUS MAFIC MINERALS; DARK GRAY TO GRAYISH BLACK ARGILLITE-PHYLLITE ROCK FRAGMENTS ARE 650/0 OF LITHICS FRACTION, GRAYISH GREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS 250/0, AND 100/0 DIVERSE MIX OF OTHER LITHIC TYPES. SAND/SANDSTONE (67901.68401) = LIGHT GRAY WITH FAINT BROWNISH GRAY SECONDARY HUES; VERY FINE UPPER TO MEDIUM LOWER; MOSTLY WELL SORTED IN FINE RANGE; NOTE APPARENT FINING UPWARD; NOTE "CLEANER" OVERALL SALT AND PEPPER APPEARANCE; ALMOST ALL DISAGGREGATED; TRACE SPOTTY ASHY CLAYEY MATRIX SUPPORTED CONSOLIDATED SANDSTONE; SUBANGULAR TO ANGULAR; NOTE SIGNIFICANTLY LESS LITHIC GRAINS THAN PREVIOUS SANDS (5-15°J'o); LITHIC QUARTZ ARENITE; 85-95°J'o QUARTZ AND GLASS. TUFFACEOUS CLA YSTONEI TUFFACEOUS SILTSTONE (68801 - 70001) = LIGHT TO MEDIUM GRAY TO GRAYISH BROWN WITH LIGHT TO MEDIUM BROWN SECONDARY HUES; SOFT TO SLIGHTLY FIRM; IRREGUALR TO SHAPELESS, AMORPHOUS CUTTINGS; SILTY TO CLAYEY TEXT EARTHY TO OCCASIONALLY MICROSPARKL Y LUSTRE; SCATTERED VISIBLE SHARDS; TRACE BLACK, MICROTHIN CARBONACEOUS LAMINATIONS;GRADING TO VERY FINE SILTY SANDSTONE AND SANDY SILTSTONE; GRAYISH CLAYSTONES GENERALLY NON CALCAREÙUS AND BROWNISH SILTSTONES ARE MODERATELY TO STRONGLY CALCAREOUS; TRACE CALCITE GRAINS; SCATTERED BLACK CARBONACEOUS MATERIAL AND THIN COALS. [;I EPOCH 19 ( ( (M)Marathon Oil Company - Falls Creek Unit #1 RD ( COAL ( 6960' - 7085') = BLACK WITH DARK DUSKY BROWN SECONDARY HUES; VERY FIRM TO MODERATELY HARD; BRITTLE; PLATY TO BLOCKY DOMINATL Y PLANAR FRACTURE, RARE BIRDEYE AND CONCHOIDAL FRACTURE;SMOOTH TO GLASSY TEXTURE; VITREOUS TO RESINOUS LUSTRE; OCCASIONALLY GRADING TO DARK BROWN CARBON ACEOUS SHALE; FIRM; SILTY TO SLIGHTLY GRITTY TEXTURE; EARTHY LUSTRE;COAL FRAGMENTS HAVE SCATTERED VISIBLE OUTGASSING BUBBLES PRESENT; TRACE AMBER ALONG BEDDING PLANES. SANDI SANDSTONE (7000' -7130') = LIGHT GRAY OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT, WHITE, LIGHT GRA Y,LIGHT GREEN TO LIGHT GREENISH GRAY, ABUNDANT BLACK LITHS GIVE SAND A "SALT AND PEPPER·' APPEARANCE,TRACE DUSKY RED TO REDDISH BROWN LITHS; VERY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED;MATRIX SUPPORTED WITH VERY ASHY TO CLAYEY; WHITE TO GRAYISH WHITE; VERY CALCAREOUS; ESTIMATE POOR POROSITY AND PERMEABILITY; TRACE BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE ( 7010' - 7190') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLIGHTLY MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; PRESENT AS SUPPORTING MATRIX ( FOR SAND; NON TO SLIGHTLY CALCAREOUS. VOLCANIC ASH (7100'-7300') = VERY LIGHT GRAY TO WHITE; OCCASIONALLY PALE BROWN LOCAL VARIATION AS EITHER PRIMARY COLOR OR SECONDARY HUE; SOFT; ASHY TEXTURE; SOFT GLASSY TO SPARKL Y LUSTRE; ABUNDANT VISIBLE SHARDS; OCCASIONALLY DISPLAYS MASSIVE CONCENTRATIONS OF APPARENT SPARKL Y MICROSHARDS; ALSO OFTEN CONTAINS COMMON TO ABUNDANT SAND GRAINS, AND IS THE SUPPORTING MATRIX MATERIAL FOR THE VERY ASHY SANDSTONE DESCRIBED ABOVE; SOME OF THE ASH IS IN VARIOUS STAGES OF DEVITRIFICATION AND REFORMATION AS A VERY TUFFACEOUS CLAYSTONE; MANY OF THE PIECES ARE PROMINENTLY MOTTLED WITH GRAY TUFFACEOUS CLAYSTONE. VERY ASHY SANDSTONE (7130'-7300') = VERY CLOSELY GRADTIONAL TO THE VOLCANIC ASH DESCRIBED ABOVE, THE ONLY SIGNIFICANT DIFFERENCE BEING THE TOTAL FRACTION OF ASH; WHITE TO VERY LIGHT GRAY TO LIGHT GRAY; SOFT TO VERY SLIGHTLY FIRM; SUBANGULAR TO ANGULAR, SUBDISCOIDAL TO SUBSPHERICAL; PERVASIVE ASH MATRIX SUPPORTED; VERY ASHY QUARTZ ARENITE; ESTIMATE 60-650/0 QUARTZ PLUS 25-30% COLORLESS AND TRANSPARENT GLASS, 5-10% LITHICS AND MAFIC MINERALS. SAND (7310'-7360') = MEDIUM LIGHT GRAY TO LIGHT GRAY; OVERALL GRAYISH ( SALT AND PEPPER APPEARANCE; VERY FINE LOWER TO FINE UPPER; U EPOC:H 20 ( ( (!!J Marathon Oil Company - Falls Creek Unit #1 RD MODERATELY WELL SORTED IN VERY FINE UPPER TO FINE LOWER RANGE; NOTE SIGNIFICANT FRACTION OF VERY FINE LOWER GRAINS THAT ARE NEAR THE SILT SIZE CUTOFF, ARE MOSTLY INDIVIDUAL CLEAR GLASS SHARDS, POSSIBLY A SECOND SEPARATE SIZE MODE, AND HAVE BEEN WINNOWED AWAY FROM THE WHITE VOLCANIC ASH; ANGULAR, DISCOIDAL TO SUBDISCOIDAL; ENTIRELY DISGGREGATED, BUT APPEARS THAT MATRIX TUFFACEOUS CLAYNOLCANIC ASH HAS BEEN COMPLETELY HYDRATED AND PRODUCE A BROWNISH WHITISH FLUID THAT IS WASHED OUT OF THE SAMPLES; GLASS-RICH QUARTZ ARENITE; 90-950/0 QUARTZ AND GLASS, TRACE FELDSPAR, 5-10% LITHICS AND MAFIC MINERALS; LITHICS ARE ROUGHLY EQUAL FRACTIONS OF ARGILLITE AND GREENSTONE METAMORPHIC ROCK FRAGMENTS. COALS (7085'-7430') = BLACK; BRITTLE TO MARGINALLY HARD; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO SUBVITREOUS TO DULL LUSTRE; DOMINANT IRREGULAR PLANAR FRACTURE; LOCALLY BIRDEYE OR CONCHOIDAL FRACTURE; VISIBLE OUTGASSING BUBBLES PRESENT; TRACES OF YELLOW RESINITE (AMBER) ALONG BEDDING PLANES. TUFFACEOUS CLAYSTONE ( 7490' -7590') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLIGHTLY MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; PRESENT AS SUPPORTING MATRIX ( FOR SAND; TRACE VISIBLE SHARDS; SLIGHT TO MODERATE CALCAREOUS. ( SAND ( 7520' - 7670') = LIGHT TO MEDIUM GRAY WITH SLIGHT "SALT AND PEPPER" APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY LIGHT GRAY, CLEAR TO TRANSLUCENT, WHITE, BLACK CARBONACEOUS LITHS, TRACE BLUISH GREEN AND BROWNISH RED; VERY FINE UPPER TO SCATTERED VERY COARSE LOWER, DOMINANT FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED WITH TRACE LOOSELY CONSOLIDATED SANDSTONE; LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TO CLAYEY SUPPORTING MATRIX; SLIGHT TO VERY CALCAREOUS; TRACE TUFFS; LOCALLY COMMON PIECES OF CONSOLIDATED VERY FINE TO FINE GRAIN SUPPORTED CALCITE CEMENTED SANDSTONE; CONSOLIDATED SANDSTONE OFTEN HAS GREENISH GRAY OR BROWISH GRAY SECONDARY HUES; SOME CONSOLIDATED PIECES HAVE IRREGULAR MICROTHIN SILT LAMINATIONS; MANY INDIVDUAL LOOSE GRAINS HAVE THIN PATCHY RIMS OF CALCITE; SUBLITHIC ARENITE TO LITHIC ARENITE; ESTIMATE 70-800/0 QUARTZ PLUS 5- 15°A, GLASS, TRACE -5°A, FELDSPAR, 15-20°A, LITHICS AND MAFIC MINERALS DOMINATED BY LIGHT TO DARK GRAY META ROCK FRAGMENTS. TUFFACEOUS CLAYSTONE (7590' -7770') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR LUMPY HABIT; ASHY TO CLAYEY TEXTURE; EARTHY TO MICROSPARKL Y LUSTRE; FAIR TO GOOD ( COHESIVENESS, POOR ADHESIVENESS; ABUNDANT SUPPORTING MATRIX ~ EPOCH 21 ( ( (M)Marathon Oil Company - Falls Creek Unit #1 RD MATERIAL OF THE SAND; CALCAREOUS IN PART; COMMONLY MOTTLED WITH VERY LIGHT GRAY TO WHITE VOLCANIC ASH; GENERALLY VISIBLE GLASS SHARDS; MOST HAS PERVASIVE "SOFT" GLASSY APPEARANCE. COALS (7430'-7800') = BLACK; BRITTLE TO MARGINALLY HARD; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO SUBVITREOUS TO DULL LUSTRE; DOMINANT IRREGULAR PLANAR FRACTURE; LOCALLY BIRDEYE OR CONCHOIDAL FRACTURE; OFTEN VISIBLE OUTGASSING BUBBLES; TRACES OF RESINITE (AMBER) ON FRACTURE SURFACES. SAND/SANDSTONE (7670'-7900') = NOTE COLOR CHANGE AT 7800' FROM MEDIUM LIGHT GRAY-MEDIUM GRAY WITH LIGHT OLIVE GRAY SECONDARY HUES TO LIGHT OLIVE GRAY-OLIVE GRAY WITH BROWNISH GRAY SECONDARY HUES; VERY FINE LOWER TO MEDIUM LOWER; MODERATELY WELL SORTED IN FINE LOWER TO FINE UPPER RANGE; ALL GROUPS OF ROUNDEDNESS AND SHAPE, BUT DOMINANT MODE IS ANGULAR TO SUBANGULAR AND SUBDISCOIDAL-SUBSPHERICAL; ABUNDANT DISAGGREGATED, WITH MANY TINY PIECES OF CONSOLIDATED GRAIN SUPPORTED CALCAREOUS CEMENTED SANDSTONE, AND MANY INDIVIDUAL GRAINS WITH SURFACE CALCITE; GENERAL Y STRONG EFFERVESCENCE; SPOTTY TUFFACEOUS SILT MATRIX SUPPORTED; SUBLITHIC TO LITHIC ARENITE; NOTE SIGNIFICANT 0J'o OF TRANSLUCENT LIGHT BROWN LITHICS GRAINS AND PALE BROWN QUARTZ; COMMON GREENISH GRAY METALITHICS. SAND (7900'-7940') = NOTE SIGNIFICANT COLOR CHANGE AND OVERALL APPEARANCE AT 7900'; LIGHT GRAY; HAS A HOMOGENOUS VERY FINE SLIGHTLY "DIRTY" SALT AND PEPPER APPEARANCE; VERY FINE LOWER TO FINE UPPER; WELL SORTED IN VERY FINE UPPER-FINE LOWER RANGE; VERY MUSHY WHEN WET, BUT CAN BE COMPACTED VERY TIGHTLY AFTER DEWATERING; ANGULAR AND DISCOIDAL; ABUNDANT VERY SHARP-EDGED GRAINS; ENTIRELY DISAGGREGATED; QUARTZARENITE; 90-95% QUARTZ AND GLASS, TRACE FELDSPAR, 5-100/0 DARK GRAY TO BLACK LITHICS PLUS MAFIC MINERALS; COLORLESS &TRANSPARENT GRAINS ARE 70% OF SAND TOTAL; NOTE VERY LARGE FRACTION OF GLASS (50%+). TUFFACEOUS CLAYSTONE (7770' - 8050') = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO SLIGHTLY FIRM; IRREGULAR LUMPY HABIT; ASHY TO CLAYEY TEXTURE; EARTHY TO MICROSPARKL Y LUSTRE; FAIR TO GOOD COHESIVENESS, POOR ADHESIVENESS; ABUNDANT SUPPORTING MATRIX MATERIAL OF THE SAND; CALCAREOUS IN PART; TRACE MOTTLED WITH VERY LIGHT GRAY TO WHITE VOLCANIC ASH; GENERALLY VISIBLE GLASS SHARDS; MOST HAS PERVASIVE "SOFT" GLASSY APPEARANCE. COALS (7800'-8200') = BLACK; BRITTLE TO MARGINALLY HARD; FRAGILE TO TOUGH; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO SUBVITREOUS ( TO DULL LUSTRE; DOMINANT IRREGULAR PLANAR FRACTURE; LOCALLY ( ( U EPOC:H 22 ( ( (.M.)Marathon Oil Company - Falls Creek Unit #1 RD ( COMMON BIRDEYE OR CONCHOIDAL FRACTURE; OFTEN HAS VISIBLE OUTGASSING BUBBLES; RARE VISIBLE YELLOW RESINITE (AMBER) ON FRACTURE SURFACES; NOTE THAT SOME PIECES HAVE A FILMY, VERY SLIGHTLY OILY APPEARANCE WHEN FLAT LAMINATIONS ARE INITIALLY PARTED. SAND/SANDSTONE (7940'- 8100') = COLOR RETURNS TO OLIVE GRAY WITH BROWNISH GRAY SECONDARY HUES; VERY FINE LOWER TO MEDIUM LOWER; RARE COARSER GRAINS; MODERATELY WELL SORTED IN FINE RANGE; ALL GROUPS OF ROUNDEDNESS AND SHAPE WERE PRESENT; DOMINANTLY SUBANGULAR-ANGULAR AND SUBDISCOIDAL- DISCOIDAL; MOSTLY DISAGGREGATED; BUT ABUNDANT TINY SANDSTONE PIECES ARE CALCAREOUSLY CEMENTED, GRAIN SUPPORTED, AND STONGL Y EFFERVESCENT; SIL TV SUBLITHIC ARENITE WITH INCREASED METALITHICS. TUFFACEOUS CLAYSTONE / TUFFACEOUS SILTSTONE ( 8160' - 8270') = LIGHT GRAY WITH LIGHT BROWN SECONDARY HUES TO LIGHT BROWNISH GRAY TO LIGHT BROWN; SOFT TO SLIGHTLY FIRM; IRREGULAR, AMORPHOUS CUTTINGS; ASHY TO CLAYEY TO SLIGHTLY GRITTY TEXTURE; DULL EARTHY TO OCCASIONALLY MICROSPARKL Y lUSTRE; FAIR TO GOOD COHESIVENESS; POOR ADHESIVENESS; NON TO SLIGHTLY CALCAREOUS; HYDROPHiliC; EXPANSIVE AND SLIGHTLY SOLUBLE; SUPPORTING MATRIX FOR SAND;TRACE,BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND ( PARTICLES THROUGHOUT; TRACES OF LIGHT GRAY TO GRAYISH WHITE TUFF (VOLCANIC ASH). SAND / SANDSTONE ( 8200' - 8300')= LIGHT GRAY TO LIGHT GRAYISH BROWN OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY TRANSPARENT TO LIGHT GRAY, SCATTERED DUSKY RED,BLACK AND GREENISH GRAY LITHS; VERY FINE LOWER TO FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL TO WELL SORTED; DISAGGREGATED WITH SCATTERED, VERY LOOSELY CONSOLIDATED SANDSTONE; ASHYI CLAYEY SUPPORTING MATRIX; NON TO SLIGHTLY CALCAREOUS. COAL (8295' - 8335') = BLACK WITH SCATTERED DARK, DUSKY BROWN SECONDARY HUES; VERY FIRM TO MODERATELY HARD; BRITTLE; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO SUBVITREOUS LUSTRE; PLANAR TO SUBBLOCKY CUTTINGS; GENERAL Y PLANAR FRACTURE WITH SCATTERED BIRDEYE AND CONCHOIDAL; TRACE AMBER ALONG BEDDING PLANES; ABUNDANT AND PROLONGED OUTGASSING BUBBLES; OCCASIONALLY GRADING TO VERY DARK BROWN, CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (8350' - 8420') = LIGHT GRAY TO LIGHT GRAYISH BROWN WITH liGHT BROWN SECONDARY HUES; SOFT TO SLIGHTLY FIRM; STICKY; IRREGULAR, CLUMPY CUTTINGS; ASHY TO CLAYEY TEXTURE; DULL ( TO MICROSPARKL Y LUSTRE; OCCASIONAL VISIBLE SHARDS PRESENT; FAIR TO ~ EPOCH 23 ( ( (!!)Marathon Oil Company - Falls Creek Unit #1 RD ( GOOD COHESIVENESS; FAIR ADHESIVENESS; NON TO SLIGHTLY CALCAREOUS; TRACE LIGHT GRAY TUFF; TRACE BLACK CARBONACEOUS MICROTHIN LAMINATIONS AND LARGER FRAGMENTS; TRACE CALCITE. SAND / SANDSTONE ( 8390' - 8500')= LIGHT GRAY TO LIGHT GRAYISH BROWN OVERALL WITH INDIVIDUAL GRAINS DOMINANTLY TRANSPARENT TO LIGHT GRAY, SCATTERED DUSKY RED,BLACK AND GREENISH GRAY LITHS; VERY FINE LOWER TO FINE UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL TO WELL SORTED; DISAGGREGATED WITH SCATTERED, VERY LOOSELY CONSOLIDATED SANDSTONE; ASHY/ CLAYEY SUPPORTING MATRIX; NON TO SLIGHTLY CALCAREOUS GRADING TO VERY FINE SANDY SILTSTONE AND SIL TV SANDSTONE. SAND/SANDSTONE (8510'-8700') = SUBTLE COLOR CHANGE FROM 8510 TO 8600; FROM MEDIUM LIGHT GRAY WITH MODERATE LIGHT BROWNISH GRAY SECONDARY HUES, TO LIGHT OLIVE GRAY WITH STRONG MEDIUM LIGHT GRAY AND/OR FAINT BROWNISH GRAY SECONDARY HUES; VERY FINE LOWER TO GRANULE; MODERATE TO POORLY SORTED OVERALL; LOCALLY IS MODERATELY WELL SORTED IN MOST ABUNDANT FRACTION FROM FINE UPPER TO MEDIUM UPPER; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; 1-50/0 IS MORE ROUNDED AND SPHERICAL; DISAGGREGATED WITH MINOR CONSOLIDATED PIECES; CONSOLIDATED SANDSTONE IS MIX OF BOTH CALCITE CEMENTED GRAIN SUPPORTED AND TUFFACEOUS CLAY ( MATRIX SUPPORTED; CONSOLIDATED PIECES ARE FRAGILE, BUT NOT FRIABLE, INDIVIDUAL GRAINS DO NOT SEPARATE APART EASILY; LITHIC TO SUBLITHIC ARENITE; NOTE THAT AS THE SAND BECOMES COARSER OVERALL, THE LITHICS FRACTION BECOMES MORE DIVERSE; CONTINUED DARK GRAY- GRAYISH BLACK-BLACK MEDIUM GRADE META (ARGILLITE-PHYLLITE) ROCK FRAGMENTS, BLACK MAFIC MINERALS, AND GRAYISH GREEN-VARIGREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS. SAND (8700'-8750') = NOTE PROMINENT CHANGE IN COLOR AND SIZE FROM SANDS IMMEDIATELY ABOVE; LIGHT GRAY, WITH VERY FINE SLIGHTLY "DIRTY" SALT AND PEPPER APPEARANCE; VERY FINE LOWER TO FINE UPPER; WELL SORTED IN VERY FINE UPPER-FINE LOWER RANGE; VERY MUSHY WHEN WET, BUT COMPACTS VERY TIGHTLY AFTER MINIMAL DRYING; ANGULAR AND DISCOIDAL; ABUNDANT VERY SHARP-EDGED GRAINS; ENTIRELY DISAGGREGATED; QUARTZ ARENITE; 90-95% QUARTZ AND GLASS, TRACE FELDSPAR, 5-10% DARK GRAY TO BLACK LITHICS PLUS MAFIC MINERALS; COLORLESS &TRANSPARENT GRAINS ARE 70-800/0 OF TOTAL SAND; ALSO NOTE APPARENT VERY LARGE FRACTION OF (VOLCANIC) GLASS (50-60%) OF SAND; AT LEAST 100/ó OF THE VERY FINE LOWER SAND IS ACTUALLY IN THE SILT RANGE. COALS (8340'-8880') = BLACK; BRITTLE TO MARGINALLY HARD; FRAGILE TO ( TOUGH; SMOOTH TO DENSE MATTE TEXTURE; RESINOUS TO SUBVITREOUS ~ EPOCH 24 (" ( ( ( ( (!ðJMarathon Oil Company - Falls Creek Unit #1 RD TO DULL LUSTRE; DOMINANT IRREGULAR PLANAR FRACTURE; LOCALLY COMMON BIRDEYE OR CONCHOIDAL FRACTURE; OFTEN HAS VISIBLE OUTGASSING BUBBLES; RARE VISIBLE YELLOW RESINITE (AMBER) ON FRACTURE SURFACES; NOTE THAT RARE PIECES HAVE A FAINTLY OILY APPEARANCE WHEN FLAT LAMINATIONS ARE INITITALL Y PARTED; LOCALLY INTERBEDDED WITH, AND GRADATIONAL TO CARBONACEOUS SHALE. SAND/SANDSTONE (8750'-8880') = MEDIUM GRAY TO MEDIUM LIGHT GRAY WITH VERY STRONG GRAYISH BROWN TO LIGHT GRAYISH BROWN AND FAINT OLIVE GREEN SECONDARY HUES; VERY FINE LOWER TO TRACE GRANULES; MODERATE TO POORLY SORTED OVERALL; DOMINANTLY IN FINE UPPER- MEDIUM LOWER RANGE; SUBANGULAR TO ANGULAR AND DISCOIDAL TO SUBDISCOIDAL; DISGGREGATED, MINOR CONSOLIDATED PIECES DOMINANTLY CALCAREOUSLY CEMENTED GRAIN SUPPORTED; SUBLITHIC ARENITE; METALITHICS AS ABOVE. COAL ( 8880' - 8900') = BLACK; VERY FIRM TO MODERATELY HARD; BRITTLE; SMOOTH TEXTURE; RESINOUS TO SUBVITREOUS LUSTRE; PLANAR FRACTURE;TRACE AMBER ALONG BEDDING PLANE;VISIBLE OUTGASSING BUBBLES PRESENT. ~ EPOCH 25 ~- '~/ 1----------- i TR I P -----------_ .DRILL .RIG REPAIRS . CMTING ACTIVITY CTEST CASING L__----==-__ '-~. /-8 H A /- TEST LlNESIBOPE / // / / ~NIPPLE UP/DOWN I / / / / /// ~DIR. WORK / // / I // RIG ACTIVITY RIG REPAIRS RIG ACTMTY SUMM~Y SLIP DRILL LINE RIG SERVICE -'''-, \ \"""" CIRCULATING~ .TRIP ElSLlP DRILL LINE . DRILL CEMENT C LEAK OFF TEST CREAM CCIRCULATING . SURVEY .WIRELlNE LOG . RIG UP/OWN EQUIP. .8 H A OFISHING ilDIR. WORK . SHORT TRIP CTOP DRIVE . TEST LlNES/80PE II CLEAN PITS f) EP(,~H MISCELLANEOUS DRILL iii RIG SERVICE IIRUN CASING CNIPPLE UP/DOWN o MISCELLANEOUS ,-.-/ -'~ --- (.M)Marathon Oil Company - Beaver Creek #10 ~\\~ tf:)~\~ DATE DEPTH MD I TVD 7/31/01 -3134'láoi5'-a~8-i47 ¡ 7 ! 16 i 9/11/14 iN/A, N/A i4-¡OTIR! 0 : 8.0! 0 i 31000 ¡ 0 8/1/01 330-7i7323i'-¡---&9T-lf-i6T24 ¡ 12/17/19ijßi1 I 5 i 0 10.251 0 ! 8.5! 0 l 30000 1160 c --s/2/of _~§~2'/ª-,45~1~=Lj}~1_-L_~~9- 1.28 i 16722723162! 1 ~-7iO I 0.5! 5 ! 9.2 10.15 i 31000 I_~_ __~j~lº1. _412?}ª856'~~_~.3_ I 49 i 10 i 27 ¡ 15/22/25 i 6.4 '2 8 0 _ 10.25 I 5 ¡ 9.1 ¡ 0.1 : 31000 I 80 _~/4!q1 _47§~~~~~~Lª_.J5_L§.o 9! 31! 16/23/27 ¡ 5.6,2 I 6 0 i TR i 7.5 i 9.2 :0.15130500! 100 8/5/01 _¡_§1~~'/46~~_;-ª_.-ª-__' 51 i 10 ¡ 30 ¡ 14/?4/26 ! 5~~2 8 O! TR I 7.5 ! 9.0 ¡ 0.1 1-3000Õ-r 120- _ªl~!911__~_675'L~!~!Lc--ª'--~' 46 ,10! 26 i 12/21/22 ! 6.8 . 1 a 0 TR j 2.5 ¡ 8.5 !9·05130000 180-- 817/01 , 5875'/5316' i 9.25 I 50 ¡ 10 ! 30 I 13/20/20 I 7.0 : 1 10 0 - ! TRl3 ! 10.0 i 0.1 i 30000 i 40 -- a/a/ö-f ~ -6510'/5941'-- 9.33 ; 48 -ITo ! 28 ! 12/21/22 17.0 i 2 9.5 0 I TR i 3 ! 10.Õ ¡ 0.1 r 31000 I 40 --§(~!º-lJ__~ßO~~l623_?'1__9.4 L 4Ll1Ò ¡ 24 i 12/22/22 i 6.9 ! 2 8.5 0 ¡ TR i 4 ! 9.0 ¡ 0.05 ¡ 31000 i 40 ª-(1º/Oj __T?_~0~L66~Lj~.28 L 44 J 10 ! 21 I 12/24/25! 7.1! 2 c- 9.0 O! TR ¡ 4.5 I 9.1 ! 0.051 32000! 40 8/11/01 7683'/7117' ¡ 9.26 ,44 9! 21 ! 13/24/25 I 7.5 ! 2 D.O O! TR! 4.5 '9.0! 9.05 i 31000! 40 -811-~7of 79391t~~Z'- i__~_.L!~4 .'. ~ I 2f 113/24/?~1 ~_! 2 l 9.0 ¡ 0 I TR ¡ 4.5 ! 9.0 ¡ 0.05 ¡ 31000 ¡ 40 8/13/01 8635'/8062" 9.2 i 40 . 9 119 I 10/19/20 j 7.2 ¡ 2 I 8.9 ¡ 0.251 TR i 5.75 I 9.0 í 0.1l31õõOT80~-" nª/~~!~f1_ ~~~QQ'L~ª~I'_ 'I 9.25 ¡ 45 ' 10 , 20 ! 12/18/25 ¡ 8.0 ! 2 ¡ 8.0 i 0.25 i TR i 5.5 ¡ 9.0 i 0.1 ¡ 32000 i 80 ª-/~_§LºJ _ª_~ºº'L8327.'_I__~·3ª_i 42 , 10 i 16 i 12/18/21 I 8.4 i 2 i 8.0 10.251 TR -i5.5 18.5!O.m200or8õ~ _~!J~£01 8900'/8327' _L_~~~_! 43 i 10 ¡ 20 i 10/21/21 ¡ 8.5 ! 2 ; 8.25 ! 0.25! TR i 6.5 I 8~§ ¡ 0.1 i_?2000 I 80 8/17/01 8900'/8327' I 9.5 ! 43 9! 16 ¡ 12/24/24 i 10.0 ¡ 2 I 9 10.25 ¡ 0.25 ¡ 7.5 j 9.5 ¡ 3.60 i 21000! 120 - - .-- ----- -------·-----í----~---- -------------¡-~--~~-, ,I MUD RECORD MW VIS PV YP FL FC SOL OIL SD MBT pH Alk Ca+ CI- GELS ---- ---- - - --- -- - ---~-- ; - ! I , ' , I : ; : - i-----·--'--------"-----'-- I I ~-- , ¡ ¡ I ~-------'----- - ----. -_._---------~---- ~ ~-~--~-~~-- -~-~ U EP('r'H ')7 -- '"-/ ",-,' ( ( ~ . IlARATHOI Marathon 0.1 Company - Beaver Creek #10 ( SURVEY RECORD # Depth Angle Azimuth Length Depth Section +N/S- +EIW- (degl Rate (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) 100f) (+) (-) 1 166.00 0.62 18.50 166.00 166.00 -0.90 0.85 0.28 0.37 0.37 2 344.00 0.88 359.90 178.00 343.98 -3.12 3.13 0.59 0.20 0.15 3 430.00 0.97 318.40 86.00 429.97 -4.06 4.34 0.10 0.77 0.10 4 540.00 1.58 270.60 110.00 539.95 -3.91 5.05 -2.03 1.07 0.55 5 646.00 2.46 250.90 106.00 645.88 -1.88 4.32 -5.64 1.05 0.83 6 737.00 3.87 241.80 91.00 736.74 1.77 2.23 -10.19 1.64 1.55 7 825.00 4.04 241.40 88.00 824.53 6.46 -0.66 -15.53 0.20 0.19 8 917.00 2.90 242.50 92.00 916.36 10.74 -3.28 -20.44 -1.24 -1.24 9 1013.00 2.55 245.70 96.00 1012.25 14.13 -5.28 -24.54 0.40 -0.36 10 1138.00 1.32 266.40 125.00 1137.18 16.77 -6.52 -28.51 1.12 -0.98 11 1322.00 0.88 334.30 184.00 1321 . 15 16.74 -5.38 -31.24 0.70 -0.24 12 1452.00 1.05 332.50 130.00 1451.13 15.30 -3.42 -32.23 0.13 0.13 13 1528.00 1.10 333.20 76.00 1527.12 14.37 -2.15 -32.88 0.07 0.07 14 1580.00 1.10 258.70 52.00 1579.11 14.32 -1.81 -33.59 2.56 0.00 15 1630.00 3.69 215.40 50.00 1629.07 16.15 -3.21 -34.99 5.97 5.18 16 1735.00 5.63 209.40 105.00 1733.72 24.54 -10.45 -39.48 1.90 1.85 17 1835.00 7.65 204.90 100.00 1833.04 36.06 -20.77 -44.69 2.08 2.02 18 1898.00 9.05 202.10 63.00 1895.37 45.20 -29.16 -48.32 2.31 2.22 19 1980.00 11.07 200.00 82.00 1976.11 59.52 -42.53 -53.44 2.50 2.46 20 2065.00 13.45 198.20 85.00 2059.16 77.54 -59.60 -59.32 2.84 2.80 21 2145.00 15.20 199.30 80.00 2136.67 97.30 -78.33 -65.69 2.21 2.19 22 2302.00 19.07 197.50 157.00 2286.68 143.44 -122.24 -80.21 2.49 2.46 ( 23 2385.00 21.20 199.60 83.00 2364.60 171.95 -149.31 -89.33 2.71 2.57 24 2464.00 23.38 200.00 79.00 2437.69 201.89 -177.50 -99.48 2.77 2.76 25 2525.00 24.43 199.60 61.00 2493.46 226.59 -200.76 -107.85 1.74 1.72 26 2648.00 27.69 199.60 123.00 2603.94 280.56 -251.65 -125.97 2.65 2.65 27 2771.00 28.74 198.90 123.00 2712.32 338.64 -306.56 -145.14 0.90 0.85 28 2894.00 28.56 198.60 123.00 2820.26 397.51 -362.40 -164.10 0.19 -0.15 29 3017.00 28.39 197.80 123.00 2928.38 456.02 -418.11 -182.41 0.34 -0.14 30 3138.00 28.30 197.50 121.00 3034.88 513.29 -472.85 -199.38 0.14 -0.07 31 3262.00 28.13 197.50 124.00 3144.14 571.73 -528.76 -217.46 0.14 -0.14 32 3385.00 28.56 199.25 123.00 3252.40 630.00 -584.17 -235.87 0.76 0.35 33 3692.00 27.77 198.20 307.00 3523.05 774.65 -721.40 -282.41 0.30 -0.26 34 3803.00 26.89 198.90 111 .00 3621.66 825.51 -769.72 -298.62 0.84 -0.79 35 3999.00 26.72 200.00 196.00 3796.60 913.80 -853.06 -328.04 0.27 -0.09 36 4122.00 27.86 201.40 123.00 3905.90 970.17 -905.80 -347.99 1.06 0.93 37 4367.00 28.65 202.10 245.00 4121.71 1086.15 -1013.52 -390.97 0.35 0.32 38 4495.00 28.13 201.70 128.00 4234.32 1147.01 -1069.99 -413.68 0.43 -0.41 39 4557.00 28.10 202.40 62.00 4289.90 1176.22 -1097.07 -424.64 0.53 -0.05 40 4680.00 27.86 202.40 123.00 4397.62 1233.93 -1150.42 -446.63 0.20 -0.20 41 4742.00 27.95 201.40 62.00 4452.41 1262.94 -1177.34 -457.46 0.77 0.15 42 4939.00 27.16 202.80 197.00 4627.07 1354.07 -1261.78 -491.73 0.52 -0.40 43 5112.00 27.77 203.80 173.00 4780.57 1433.84 -1335.05 523.29 0.44 0.35 44 5251.00 27.07 204.20 139.00 4903.95 1497.81 -1393.53 -549.32 0.52 -0.50 45 5332.00 28.21 204.70 81.00 4975.71 1535.36 -1427.74 -564.88 1.44 1.41 46 5420.00 27.77 202.80 88.00 5035.42 1576.64 -1465.53 -581.52 1.13 -0.50 47 5352.00 26.72 203.50 232.00 5259.68 1682.82 1563.19 -623.26 0.47 -0.45 48 5721.00 26.28 204.20 69.00 5321.43 1713.60 -1591.35 -635.71 0.78 -0.64 49 5800.00 25.58 203.80 79.00 5392.47 1748.12 -1622.91 -649.76 0.91 -0.89 ( 50 5935.00 23.73 202.40 135.00 5515.16 1804.42 -1674.69 -671.87 1.44 -1.37 51 6058.00 21.80 202.80 123.00 5628.58 1852.01 -1718.63 -690.16 1.57 -1.57 52 6131.00 21.36 204.20 73.00 5696.46 1878.85 -1743.25 -700.86 0.93 -0.60 53 6232.00 20.39 202.10 101.00 5790.83 1914.83 -1776.33 -715.02 1.21 -0.96 o EPOCH 28 ( 54 6331.00 55 6434.00 56 6498.00 57 6591.00 58 6684.00 59 6783.00 60 6868.00 61 6969.00 62 7089.00 63 7174.00 64 7274.00 65 7407.00 66 7510.00 67 7694.00 68 7816.00 69 7945.00 70 8039.00 ( ( 18.90 15.64 14.85 15.21 11.78 11.87 11.16 9.93 8.88 7.56 5.36 2.37 0.09 0.35 0.35 0.35 0.44 ( " @ ( ~Marathon Oil Company - Beaver Creek #10 201.10 202.80 201.70 202.40 201.70 201.40 200.00 200.00 198.50 199.60 203.50 201.00 96.30 146.90 184.50 166.90 189.80 99.00 5884.06 1948.11 -1807.27 -727.28 103.00 5982.41 1978.68 -1835.64 -738.67 64.00 6044.16 1995.51 1851.22 -745.04 93.00 6133.97 2019.63 -1873.57 -754.10 93.00 6224.36 2041.32 -1893.68 -762.26 99.00 6321.29 2061.61 -1912.54 -769.71 85.00 6404.58 2078.57 -1928.41 -775.72 101.00 6503.87 2097.04 -1945.78 -782.04 120.00 6622..26 2116.63 -1964.29 -788.51 85.00 6706.38 2128.76 -1975.78 -792.47 100.00 6805.74 2140.00 -1986.26 -796.54 133.00 6938.43 2148.97 -1994.53 -800.01 103.00 7041.40 2151.09 -1996.48 -800.84 184.00 7225.40 2151.40 -1996.89 -800.66 122.00 7347.39 2151.97 -1997.57 -800.49 129.00 7476.39 2152.66 -1998.35 -800.43 94.00 7570.39 2153.25 -1998.98 -800.43 ~EPOCH 1.54 3.20 1.31 0.43 3.69 0.11 0.90 1.22 0.60 1.56 2.24 2.25 2.31 0.23 0.18 0.08 0.19 -1.51 -3.17 -1.23 0.39 -3.69 0.09 -0.84 -1.22 -0.87 -1.55 -2.20 -2.25 -2.21 0.14 0.00 0.00 0.10 29 C.\~\j. \ \þ,\. tQ\\\ (!!)Marathon Oil Company - Beaver Creek #10 BIT RECORD .-~- !SER NO.¡JETS!DEPTHPEPTHjFTG!HRSiROP! WOB I RPM ; PP; GRADE , ¡ i ~ í ¡ ¡ ; i ! , i IN i OUT ¡ , ¡Avg ¡(Hi-Lo) Avg[(Hi-Lo) AvgKHi-Lo) Avgjl - 0 - D - L - B - G - OT - R . ;: ! ; ~;: f ~ . ______ _1J 8.5 _3-~IL~_c:;_~~BINATION__N/A : N/A ! 3094 I 3134 I 40 110.341 3.9 I N/A i N/A ' N/A N/A __~J~!5 - _ _n~T£~~~___~MS;924~Ê x 131 3134 i 3979 1845 !18.53i45.6L 10 40'~i 1000 _~-3-WT-A-E-1-SD-HR 3 16.75 STC MF15PS ! LS7434:3 x 131 3979 ! 4923 1944 Q1.02!44.9i 15 40.0 ¡ 1400 ! 3-3-WT-A-F-1-NO-HR ----¡ --- --------- ------.-----, ¡ ; - j ;-! r; : ~----+-- 4 :6.75 STC MF15 ' LS7522 3 X 131 4923 ¡ 5675 ¡ 752117.83142.2! 15 ¡ 55.0 1550 i 3-3-WT-A-E-1-SD-HR __~16-,-~~==ST~=~~i~i~cjp~~ L'(954-1-3X 13i 5675 j 66~~ !102~32.87i31.1! -1-5-- ¡ 60.0 170~ 1-2-ER-H-E-1-NO-H~__ 6 16.75 STC XR20TDGPS : LY9623 ¡3X 1316698 i 7815 11117~5.30i24.7! 15 i 30.0 , 1800 ! 3-3-ER-A-E-1-NO-HR --.--;.-----~-------------~-~-- ¡ ; --¡--: r ; ¡--- i ~->--- 7 i6_-?5 _ STC ~~20!_~~!:S L Y9537 :3 x 131 7815 i 8900 !1085131.47134.6! ~-L-35.0 2500 3-3-ER-M-E-BT-TD # i II BI~IZEi TYPE - - --- --- --------- ---------------- -~-~-----~ '.-- n EP0r:H "",-, '~ ,~ MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD { REPORT FOR ROWLAND LAWSON DATE Jul31, 2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5" DAILY WELLSITE REPORT (" [:I EPOCH DEPTH 3134 YESTERDAY 3103 PRESENT OPERATION= MIXING NEW MUD 24 Hour Footage 31 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SIN NIA INTERVAL IN OUT 3094 3134 HOURS 10.34 CONDITION T/B/C NIA REASON PULLED NIA TYPE 3-MiII Combination DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.8 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) (ITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL JETS N/A FOOTAGE 40 HIGH LOW 16.2 @ 3115 0.9 @ 3119 821 @ 3134 525 @ 3115 19 @ 3134 7 @ 3116 @ @ 816 @ 3106 806 @ 3131 DEPTH: 3118 I 3060TVD 108 PV 19 YP 32 FL 8.8 2.5 SO TR OIL 0 MBL AVERAGE 7.7 765,2 14.0 CURRENT AVG 1.6 821.0 19.7 ftlhr amps Klbs RPM psi 842.0 812 Gels pH 6/8/8 9.0 CL- 30000 1280 Ca+ CCI HIGH LOW AVERAGE 19 @ 3115 2 @ 3134 9.5 TRIP GAS= @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 3911 @ 3115 528 @ 3134 1904.4 CONNECTION GAS HIGH= @ @ AVG= @ @ CURRENT @ @ CURRENT BACKGROUNDIAVG 1.5/3 @ @ NONE lITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Sand, Argillaceous Claystone PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE, ARGILLACEOUS CLAYSTONE, SAND DAILY ACTIVITY SUMMARY Mill from 3103' to 3110'. Drill 24' of open hole with mill from 3110' to 3134'. Circulate bottoms up. Pump sweep and circulate hole clean. Pull mill Into casing. Clean mud pits. Mix new Flo-Pro mud. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( CONFIDENTIAL MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR ROWLAND LAWSON DATE Aug 01, 2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 3 6.75 TYPE STC XR DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.9 VIS 48 FC SOL 5.0 MWD SUMMARY INTERVAL TO TOOLS ( jAS SUMMARY(units) DITCH GAS CUTIING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL DAILY WELLSITE REPORT ( U EPOCH DEPTH 3307 YESTERDAY 3134 PRESENT OPERATION= WORKING ON #2 MUD PUMP 24 Hour Footage 173 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3232 24.80 268.70 3168.84 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PU LLED MG9246 3 x 13 3134 173 3.54 In Hole HIGH LOW AVERAGE CURRENT AVG 122.3 @ 3219 1.6 @ 3134 61.8 39.0 ftlh r @ @ amps 19 @ 3134 @ 3168 8.1 7.2 Klbs @ @ RPM 1356 @ 3268 812 @ 3134 1189,5 1277 psi DEPTH: 3305 / 3235TVD PV 6 YP 25 FL 8.8 Gels 12/17/18 CL- 30000 SD 1/4 OIL 0 MBL 0 pH 8.7 Ca+ 180 CCI HIGH LOW AVERAGE 34 @ 3218 2 @ 3146 15.4 TRIP GAS= 3 @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 7454 @ 3218 279 @ 3136 3188,0 CONNECTION GAS HIGH= @ @ AVG= @ @ CURRENT @ @ CURRENT BACKGROUND/AVG 2 { 15 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Sand. Minor Argillaceous Claystone, Siltstone, Carbonaceous Shale. Ver¡ Minor Coal, Calcareous Tuff, Shale PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE, ARGILLACEOUS CLAYSTONE, SILSTSTONE, SAND Monitor well. Mix FLOPRO mud. Hold safety meeting. Build and circulate and condition mud to 8,7ppg. Circulate at 200spm, Hold PJSM for leakoff DAILY test. Break circulation. Bring BJ pumping unit on line. Pressure test lines to 2500psi. Run Leak Off Test (observed 15.5 equiv. ppg). Rig down BJ. ACTIVITY Clean pill pit. Mix and pump dry job. POOH. Lay down BHA and handling tools. Pick up and make up BHA. Pick up 26 joints 3.5" HWDP. Surface test SUMMARY MWD. RIH wth 4" drill pipe. Orient MWD tool at window. Change out swab on Mud pump #1. Drill from 3134' to 3307'. Blew hydraulic hose on Mud pump #2. POOH to window. Work on pump #2. Run one stand into open hole and break circulation. Begin CBU on pump #1 while continuing work on pump #2. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( J" ~, MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR ROWlAND LAWSON DATE Aug 02, 2001 TIME 24:00 DAILY WELLSITE REPORT g EPOCH DEPTH 3501 YESTERDAY 3307 24 Hour Footage 194 PRESENT OPERATION= DRILLING CASING INFORMATION 95/8" @ 3094' SURVEY DATA DEPTH 3483 INCLINATION 34,70 AZIMUTH 275.50 VERTICAL DEPTH 3384.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE lYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6,75 STC XR MG9246 3 x13 3134 367 8.88 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.2 @ 3385 6.0 @ 3491 53.8 17.3 ftIh r SURFACE TORQUE @ @ amps WEIGHT ON BIT 15 @ 3411 2 @ 3479 10.1 12.0 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE 1277 @ 3307 530 @ 3308 1073.8 979 psi DRILLING MUD REPORT DEPTH: 3542/ 3432lVD MW 9.1 VIS 52 PV 9 YP 28 FL 6.2 Gels 16/22/23 CL- 31000 FC 1 SOL 7.0 SO 0,5 OIL 0 MBL 5.0 pH 9.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS ( 1AS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 82 @ 3476 5 @ 3317 16.1 TRIP GAS= CUTTING GAS @ @ WIPER GAS= 10 CHROMA TOGRAPHY(ppm) SURVEY= METHANE(C-1) 16535 @ 3476 1047 @ 3317 3257.7 CONNECTION GAS HIGH= ETHANE(C-2) 20 @ 3476 1 @ 3483 0.6 AVG= PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 12/25 PENTANE(C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Sand/Sand, Carbonaceous,Shale Minor Argillaceous Claystone, Siltstone Very Minor Calcareous Tuff, Coal PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE DAILY ACTIVITY CBU while continuing to work on mud pump #2. Rig up BJ pumping unit. Change liners on Pump #1 to 5". Pick up and clean work areas. SUMMARY Test BJ pump. Drill from 3307' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( ( [:I EPOCH DAILY WELLSITE REPORT MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR ROWLAND LAWSON DATE Aug 03, 2001 TIME 24:00 PRESENT OPERATION= DRILLING DEPTH 4070 YESTERDAY 3501 24 Hour Footage 569 CASING INFORMATION 95/8" @ 3094' VERTICAL DEPTH 3710.44 3801.66 AZIMUTH 280.40 280.60 INCLINATION 45.10 44.10 DEPTH 3921 4049 SURVEY DATA CONDITION T/B/C REASON PULLED Hours INTERVAL IN OUT 3134 3979 3979 BIT INFORMATION NO. SIZE 3 6.75 4 6.75 HOURS 18,53 1.92 FOOTAGE 845 91 JETS 3 x 13 3 x 13 SIN MG9246 LS7434 TYPE STC XR STC MF15PS In Hole AVERAGE 65.2 CURRENT AVG 19.4 HIGH LOW 223.4 @ 3731 8.0 @ 3634 @ @ 16 @ 4042 0 @ 3729 @ @ 1487 @ 3927 954 @ 3503 DEPTH: 4127/3856TVD 49 PV 10 YP 27 FL 6.4 8.0 SO 0,25 OIL 0 MBL 5,0 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 2 SOL ftIhr amps Klbs RPM psi 9.5 12,1 1187 1202.4 15/22/25 9.1 CL- Gels pH 31000 80 CCI Ca+ MWD SUMMARY INTERVAL TO ( ')OLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE 71 @ 4061 6 @ 3829 21.2 TRIP GAS= 30 @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 14295 @ 4061 1483 @ 3829 4313.4 CONNECTION GAS HIGH= 19 @ 3511 @ 1.1 AVG= @ @ CURRENT @ @ CURRENT BACKGROUND/AVG 12/35 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Argillaceous Claystone, Siltstone, Coal, Carbonaceous Shale PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, ARGILLACEOUS CLAYSTONE, COAL DAILY ACTIVITY Drill and slide from 3501' to 3541 '. Circulate and condition mud at 7.75 bbls/min with BJ pump. Drill from 3541' to 3979'. CBU with rig pump and SUMMARY then CBU with BJ pump. POOH to 3130'. CBU with BJ pump at 7.75 bbls/min, Mix and pump dry job. POOH. Change out bit. Make up new bit. RIH with BHA. RIH with 4" drill pipe, Drill and slide from 3979' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR ROWLAND LAWSON DATE Aug 04, 2001 TIME 24:00 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE 4 6.75 TYPE STC M15PS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.15 VIS FC 2 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 ( (' [:t EPOCH DAILY WELLSITE REPORT DEPTH 4697 YESTERDAY 4070 24 Hour Footage 627 DEPTH INCLINATION 4362 43.10 4678 38.40 INTERVAL SIN JETS IN OUT LS7434 3 x13 3979 HIGH 211.4 @ 4549 5.6 @ 19 @ 4120 3 @ 1490 @ 4605 1026 PRESENT OPERATION= DRILLING AZIMUTH VERTICAL DEPTH 280.70 4031.15 276.90 4269.93 CONDITION FOOTAGE HOURS T/B/C 718 15.54 In Hole LOW AVERAGE CURRENT AVG @ 4484 59.5 47.3 @ @ 4421 11.1 8.2 @ @ 4120 1269.9 1337 REASON PULLED ft/hr amps Klbs RPM psi 50 6,0 PV SO DEPTH: 4753/ 4329TVD 9 YP 31 FL TR OIL 0 MBL CCI Gels pH 16/23/27 9.2 CL- Ca+ 30500 100 5.6 7.5 HIGH LOW AVERAGE 439 @ 4590 3 @ 4480 66.3 TRIP GAS= @ @ WIPER GAS= 62 CHROMATOGRAPHY(ppm) SURVEY= 84686 @ 4590 848 @ 4480 13203.9 CONNECTION GAS HIGH= 44 @ 4282 1 @ 4676 9.1 AVG= 24 @ 4272 @ 2.3 CURRENT 7 @ 4280 @ 0.2 CURRENT BACKGROUND/AVG 24/40 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major: Sand/Sandstone, Tuffaceous Claystone. Minor: Argillaceous Claystone, Siltstone, Carbonaceous Shale, Coal. Very Minor to Trace: Tuffaceous Siltstone, Calcareous Tuff, Argillaceous Shale, Tuffaceous Shale, Volcanic Ash. SAND/SANDSTONE, TUFFACEOUS CLAYSTONE DAILY ACTIVITY Drill and slide from 4070' to 4296'. CBU with rig pump. CBU with BJ unit Drill and slide from 4296' to 4610'. CBU with rig pump, CBU twice with BJ SUMMARY pump. POOH to 3130' and CBU with BJ pump. Do various rig maintenance jobs (carrier, Top Drive, blocks, crown, pump up compensator, change #2 shaker screen, install new shaker link switch). RIH with 4" drill pipe. Drill from 461 A' to report depth, Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( MARATHON Oil COMPANY DAIL Y WELLSITE REPORT FAllS CREEK UNIT NO.1 RD ( REPORT FOR ROWlAND LAWSON DATE Aug 05,2001 DEPTH 5102 TIME 24:00 YESTERDAY 4697 24 Hour Footage 405 CASING INFORMATION 95/8" @ 3094' DEPTH INCLINATION AZIMUTH SURVEY DATA 4865 35.30 274.50 5055 32.40 275.80 BIT INFORMATION NO. SIZE 4 6.75" 5 6.75" TYPE STC M15PS STC MF15 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRilLING MUD REPORT MW 9.3 VIS FC 2 SOL ( MWD SUMMARY INTERVAL TOOLS TO 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 ( ~ EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 4419.92 4577.46 INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C lS7434 3 x 13 3979 4923 944 21,02 3-3-WT-A-F-1-NO-HR LS7522 3 x 13 4923 179 4.35 In Hole HIGH LOW AVERAGE CURRENT AVG 196.7 @ 5008 7.9 @ 4935 51.8 58,9 @ @ 17 @ 4815 5 @ 4796 11.5 12.2 @ @ 1596 @ 5056 1128 @ 4803 1398,1 1435 51 8.0 PV SO DEPTH: 5124/4636TVD 10 YP 30 Fl TR Oil 0 MBl 5.8 7.5 Gels pH 14/24/26 9.0 CL- Ca+ REASO N PUllED Bit Hours ftIhr amps Klbs RPM psi 30000 120 CCI HIGH LOW AVERAGE 155 @ 4952 18 @ 4834 52.8 TRIP GAS= 60 @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 31690 @ 4952 3731 @ 4834 10577.2 CONNECTION GAS HIGH= 19 @ 4789 @ 8.8 AVG= 12 @ 4951 @ 1.7 CURRENT @ @ CURRENT BACKGROUND/AVG 24/54 @ @ LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Tuffaceous Claystone, Sand/Sandstone, Carbonaceous Shale/Coal. Minor Volcanic Ash, Siltstone, Argillaceous Claystone, Tuffaceous Siltstone, Tuffaceous Shale. Very Minor to Trace Conglomeratic Sand, Calcareous Tuff, Argillaceous Shale TUFFACEOUS CLAYSTONE, SAND/SANDSTONE, CARBONACEOUS SHALE/COAL DAIL Y ACTIVITY Drill from 4697' to 4736'. Rig generator #2 failed, rig power down for 20 minutes. Restore rig power. Drill from 4736' to 4923', CBU with rig pump. SUMMARY CBU with BJ pump, POOH. Break Bit #4 and make up Bit #5. RIH with BHA RIH with 4" drill pipe to 3106', Service rig. Continue RIH with 4" drill pipe. Drill and slide from 4923' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( (' MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( . REPORT FOR ROWlAND LAWSON DATE Aug 06,2001 TIME 24:00 DAILY WELLSITE REPORT ~ EPOCH DEPTH 5675 YESTERDAY 5102 PRESENT OPERATION= CIRCULATING 24 Hour Footage 573 CASING INFORMATION 95/8" @ 3094' SURVEY DATA DEPTH 5307 5556 INCLINATION 27.90 22.60 AZIMUTH 274.30 271.00 VERTICAL DEPTH 4795.00 5021,09 BIT INFORMATION NO. SIZE 5 6.75" TYPE STC MF15 SIN LS7522 JETS 3 x 13 INTERVAL IN OUT 4923 5675 FOOTAGE 752 HOURS 17.83 CONDITION T/B/C In Hole REASON PU LLED HOURS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 1 SOL HIGH LOW 239.3 @ 5374 10.2 @ 5307 @ @ 21 @ 5181 2 @ 5554 @ @ 1678 @ 5436 1238 @ 5438 AVERAGE 54.6 CURRENT AVG 36.0 12,7 12.2 ftIhr amps Klbs RPM psi 1472.1 1341 46 8.0 PV SO DEPTH: 5675 /5132TVD 10 YP 26 FL TR OIL 0 MBL 6.8 2,5 Gels pH 12/21/22 8.5 CL- Ca+ 30000 80 CCI MWD SUMMARY INTERVAL TO TOOLS ( .3AS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE 212 @ 5251 7 @ 5463 70.6 TRIP GAS= @ @ WIPER GAS= CH ROMA TOGRAPHY(ppm) SU RVEY= 43452 @ 5523 1479 @ 5463 14246,3 CONNECTION GAS HIGH= 35 @ 5449 1 @ 5490 10.1 AVG= 21 @ 5254 @ 4.2 CURRENT @ @ CURRENT BACKGROUND/AVG 34/88 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY Major Tuffaceous Claystone, Sand/Sandstone, Carbonaceous Shale/Coal. Minor Volcanic Ash, Siltstone, Argillaceous Claystone, Tuffaceous Siltstone, Tuffaceous Shale. Very Minor to Trace Calcareous Tuff, Conglomeratic Sand. SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, CARBONACEOUS SHALE/COAL DAILY ACTIVITY Drill from 5102' to 5240', CBU with rig pump, and CBU with BJ pump. Drill from 5240' to 5365', CBU with rig pump and CBU with BJ pump. SUMMARY Drill and slide from 5365' to 5675'. CBU with rig pump and CBU with BJ pump, Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( MARATHON OIL COMPANY DAILY WELLSITE REPORT FALLS CREEK UNIT NO.1 RD ( REPORT FOR ROWU\ND LAWSON DATE Aug 07, 2001 DEPTH 5900 TIME 24:00 YESTERDAY 5675 24 Hour Footage 225 CASING INFORMATION 95/8" @ 3094' DEPTH INCLINATION AZIMUTH SURVEY DATA 5741 19.10 271.20 5866 16.40 269.90 BIT INFORMATION NO. SIZE 5 6.75" 6 6.75" TYPE STC MF15 STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.25 VIS FC 1 SOL MWD SUMMARY INTERVAL TO ( fOOLS 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 ~:'i U EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 5193.99 5313.02 INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C lS7522 3 x 13 4923 5675 752 17.83 3-3-WT-A-E-1-SD-HR l Y9541 3x13 5675 225 4.97 In Hole HIGH LOW AVERAGE CURRENT AVG 169,0 @ 5738 9.5 @ 5678 61.1 34.2 @ @ 31 @ 5684 3 @ 5738 14.2 12.5 @ @ 1689 @ 5889 1298 @ 5737 1516.2 1469 50 10.0 DEPTH: 5875/5321ìVD 10 YP 30 FL TR OIL 0 MBL Gels pH 13/20/20 10.0 CL- Ca+ REASO N PULLED HOURS ftIhr amps Klbs RPM psi 30000 40 CCI 7.0 3.0 PV SO HIGH LOW AVERAGE 405 @ 5836 13 @ 5799 134,9 TRIP GAS= 88 @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 81107 @ 5836 2668 @ 5799 27532.4 CONNECTION GAS HIGH= 79 @ 5826 2 @ 5801 21.7 AVG= 27 @ 5719 @ 10.5 CURRENT 8 @ 5836 @ 0.6 CURRENT BACKGROUND/AVG 14/110 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone. Minor Tuffaceous Siltstone, Coal/Carbonaceous Shale. Very Minor to Trace Volcanic Ash, Conglomeratic Sand. SAND/SANDSTONE, TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY CBU with BJ pump. POOH 15 stands. Pump dry job. POOH. Test BOPE. Make up Bit #6. Orient MWD. RIH with BHA and drill pipe to 3094'. Slip and cut drill line. Repair kick springs and adjust kick rollers. Inspect brake linkage. Continue RIH to bottom. Drill and slide from 5675' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD {: REPORT FOR JERRY LORENZEN DATE Aug 08, 2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 6 6.75" ( (' DAILY WELLSITE REPORT [j EPOCH DEPTH 6520 YESTERDAY 5900 PRESENT OPERATION= DRILLING 24 Hour Footage 620 INCLINATION AZIMUTH VERTICAL DEPTH 13.60 271.70 5553.41 9.10 270.80 5864,22 INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C L Y9541 3 x 13 5675 845 25.92 In Hole HIGH LOW AVERAGE CURRENT AVG 167.6 @ 6429 8.6 @ 6182 39.9 20.0 @ @ 39 @ 6056 8 @ 6173 16.6 19.2 @ @ 1693 @ 6501 1290 @ 6110 1514.3 1570 DEPTH 6115 6432 TYPE STC XR20TDGPS REASON PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.33 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS ( jAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ftlhr amps Klbs RPM psi 48 9,5 PV SO DEPTH: 6510 /5941TVD 10 YP 28 FL TR OIL 0 MBL CCI 12/21/22 10.0 CL- Ca+ 31000 40 Gels pH 7.0 3.0 HIGH LOW AVERAGE 508 @ 6416 4 @ 5974 54,1 TRIP GAS= 0 @ 6520 0 @ 6520 0.0 WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 101589 @ 6416 884 @ 5974 10788.5 CONNECTION GAS HIGH= 64 @ 6414 @ 7.9 AVG= 44 @ 6411 @ 4.3 CURRENT 22 @ 6415 @ 0.6 CURRENT BACKGROUND/AVG 5/25 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone. Minor Coal/Carbonaceous Shale, Volcanic Ash, Tuffaceous Shale. Very Minor to Trace Conglomeratic Sand, Calcareous Tuff. SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Drill and slide from 5900' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 09,2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO, SIZE 6 6,75" 7 6.75" TYPE STC XR20TDGPS STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 2 SOL MWD SUMMARY INTERVAL TO ( reOLS 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 ,j' ~ DAILY WELLSITE REPORT U EPOCH DEPTH 6803 YESTERDAY 6520 PRESENT OPERATION= DRILLING REASON PULLED HOURS fVhr amps Klbs RPM psi 31000 40 CCI 24 Hour Footage 283 DEPTH 6620 6745 INCLINATION 7.00 5.70 VERTICAL DEPTH 6050.39 6174.69 HIGH LOW AVERAGE 169 @ 6725 5 @ 6559 44.7 TRIP GAS= 151 @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SU RVEY= 33831 @ 6725 1055 @ 6559 8928.4 CONNECTION GAS HIGH= 30 @ 6728 @ 6.7 AVG= 23 @ 6728 @ 2.4 CURRENT @ @ CURRENT BACKGROUND/AVG 11/45 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION AZIMUTH 269.20 276.10 INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C L Y9541 3 x 13 5675 6698 1023 32,87 1-2-ER-H-E-1-NO-HR LY9623 3 x 13 6698 105 3.40 In Hole HIGH LOW AVERAGE CURRENT AVG 222.2 @ 6587 8,0 @ 6530 36.5 44.2 @ @ 23 @ 6788 8 @ 6641 15.4 12.1 @ @ 1762 @ 6636 1424 @ 6620 1603.3 1516 47 8.5 DEPTH: 6803/6232TVD 10 YP 24 FL TR OIL 0 MBL Ca+ Gels pH 12/22/22 9.0 CL- PV SD 6.9 4.0 LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone. Minor Tuffaceous Shale, Volcanic Ash, Conglomeratic Sand. Very Minor to Trace Coal, Calcareous Tuff, SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE DAILY ACTIVITY Drill from 6520' to 6698'. CBU. Pump pill. POOH. Change out bit. Service rig. Repair pillar block brake linkage. Change out MWD battery, RIH SUMMARY with BHA. Surface test MWD. Continue RIH, Break circulation at the window. Continue RIH. Drill from 6698' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 10,2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 7 6.75" :( ,( U EPOCH DAILY WELLSITE REPORT DEPTH 7263 YESTERDAY 6803 PRESENT OPERATION= DRILLING 24 Hour Footage 460 DEPTH 6932 7179 AZIMUTH 278.20 259.90 VERTICAL DEPTH 6360.71 6606,80 INCLINATION 5.90 4.80 SIN LY9623 INTERVAL IN OUT 6698 CONDITION T/B/C In Hole REASON PUllED FOOTAGE 565 HOURS 22.96 TYPE STC XR20TDGPS JETS 3 x 13 DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRilLING MUD REPORT MW 9.25 VIS FC 2 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 HIGH LOW AVERAGE 423.6 @ 7070 9.1 @ 7107 33.3 @ @ 34 @ 6951 4 @ 6991 17.6 @ @ 1805 @ 7179 1426 @ 7053 1657.0 CURRENT AVG 24.4 ftlhr amps Klbs RPM psi 18.8 1715 44 9.0 PV SO DEPTH: 7250 /6677TVD 10 YP 21 Fl TR Oil 0 MBl CCI Gels pH 12/24/25 9.1 Cl- Ca+ 7.1 4.5 32000 40 HIGH lOW AVERAGE 164 @ 6831 4 @ 7108 30.7 TRIP GAS= @ @ WIPER GAS::: CHROMATOGRAPHY(ppm) SURVEY::: 32791 @ 6831 858 @ 7108 6143.1 CONNECTION GAS HIGH::: 28 @ 6847 @ 3.6 AVG::: 15 @ 6828 @ 1.8 CURRENT 4 @ 6831 @ 0,1 CURRENT BACKGROUND/AVG 13/35 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Volcanic Ash, Coal. Minor Tuffaceous Shale, Carbonaceous Shale, Very Minor to Trace Calcareous Tuff. SANDSTONE/SAND, TUFFACEOUS SilTSTONE, TUFFACEOUS CLAYSTONE, COAL DAilY ACTIVITY SUMMARY Drill from 6803' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( ( ~ EPOCH DAILY WELLSITE REPORT MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 11,2001 TIME 24:00 PRESENT OPERATION= DRILLING DEPTH 7692 YESTERDAY 7263 24 Hour Footage 429 CASING INFORMATION 95/8" @ 3094' INCLINATION AZIMUTH VERTICAL DEPTH 2.70 257.40 6797.46 1.50 243.70 7052.19 INTERVAL CONDITION JETS IN OUT FOOTAGE HOURS T/B/C 3 x 13 6698 994 40.52 In Hole LOW AVERAGE CURRENT AVG 7543 9.4 @ 7456 38.5 17.0 @ 7577 3 @ 7536 18.6 33.4 @ 7569 1413 @ 7555 1749.4 1729 DEPTH 7370 7625 SURVEY DATA REASON PULLED BIT INFORMATION NO. SIZE 7 6,75" SIN L Y9623 HIGH 284.1 @ @ 37 @ @ 1854 @ TYPE STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.26 VIS FC 2 SOL fUhr amps Klbs RPM psi DEPTH: 7683 / 711 OTVD 9 YP 21 FL TR OIL TR MBL CL- Ca+ 31000 40 13/24/25 9.0 Gels pH 7.5 4.5 PV SO 44 9.0 CCI MWD SUMMARY INTERVAL TO TOOLS ( HIGH LOW AVERAGE 824 @ 7343 8 @ 7634 97.1 TRIP GAS= @ @ WIPER GAS= 111 CHROMATOGRAPHY(ppm) SU RVEY= 164524 @ 7343 1730 @ 7634 19413,9 CONNEèTION GAS HIGH= 183 @ 7343 @ 19.6 AVG= 85 @ 7343 @ 8.8 CURRENT @ @ CURRENT BACKGROUND/AVG 8/25 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL Major Sand/Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Volcanic Ash. Minor Coal/Carbonaceous Shale. Very Minor to Trace Calcareous Tuff, Conglomeratic Sand. LITHOLOGY PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE, COAL DAILY ACTIVITY SUMMARY Drill from 7263' to 7492', CBU. POOH for 15 stand wiper trip. Test run #2 mud pump. RIH to 7492'. Drill from 7492' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( MARATHON OIL COMPANY DAILY WELLSITE REPORT FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 12, 2001 DEPTH 7949 TIME 24:00 YESTERDAY 7692 24 Hour Footage 257 CASING INFORMATION 95/8" @ 3094' DEPTH INCLINATION AZIMUTH SURVEY DATA 7688 1,10 231.70 7836 0.70 227.1 0 BIT INFORMATION NO. SIZE 7 6.75" 8 6.75" ìYPE STC XR20TDGPS STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,3 VIS FC 2 SOL ( MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL l' ( [:I EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 7115.18 7263.16 INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C LY9623 3 x 13 6698 7815 1117 45,30 3-3-A-E-1-NO- TQ L Y9537 3x13 7815 134 3,23 In Hole HIGH LOW AVERAGE CURRENT AVG 315.5 @ 7922 10.0 @ 7695 61.8 19.5 @ @ 33 @ 7693 10 @ 7787 17.6 17.0 @ @ 2603 @ 7920 1698 @ 7695 2237.4 2414 44 9.0 PV SD DEPTH: 7930 / 7357TVD 9 YP 21 FL TR OIL TR MBl 6.9 4.5 Gels pH 13/24/24 9.0 CL- Ca+ REASON PULLED NERVOUS fUhr amps Klbs RPM psi 31000 40 CCI HIGH LOW AVERAGE 885 @ 7918 10 @ 7770 152.0 TRIP GAS= 304 @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SURVEY= 176550 @ 7918 2184 @ 7770 30347,6 CONNECTION GAS HIGH= 220 @ 7918 @ 37.7 AVG= 76 @ 7918 @ 14.7 CURRENT 22 @ 7918 @ 1.8 CURRENT BACKGROUND/AVG 16/150 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Sand/Sandstone, Tuffaceous Claystone, Coal, Tuffaceous Siltstone, Minor Volcanic Ash, Tuffaceous Shale. PRESENT LITHOLOGY SAND/SANDSTONE, TUFFACEOUS CLAYSTONE, COAL Drill from 7692' to 7815'. Put #2 Mud Pump back on hole at 7727'. CBU. Pump pill. POOH. Break bit and lay down motor. Make up bit and pick up DAILY ACTIVITY motor, Service rig. Make up BHA, picking up more 3 1/2" HWDP. Test MWD. RIH to 4636'. Fill pipe. RIH. Tag fill at 7777'. Wash to 7815'. Drill SUMMARY from 7815' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( ( ( g EPOCH DAILY WELLSITE REPORT MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 13, 2001 TIME 24:00 PRESENT OPERATION= DRILLING DEPTH 8638 YESTERDAY 7949 24 Hour Footage 689 CASING INFORMATION 95/8"@ 3094' INCLINATION AZIMUTH VERTICAL DEPTH 0.40 294.40 7891.15 INTERVAL CONDITION JETS IN OUT FOOTAGE HOURS T/B/C 3 x 13 7815 823 23.63 In Hole LOW AVERAGE CURRENT AVG 8460 15.6 @ 8186 45.7 29.9 @ 8321 4 @ 8319 18.8 15.2 @ 8609 1981 @ 8361 2401.9 2488 DEPTH 8464 SURVEY DATA REASON PULLED BIT INFORMATION NO. SIZE 8 6.75" SIN L Y9537 HIGH 519.9 @ @ 23 @ @ 2650 @ TYPE STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC 2 SOL ftIhr amps Klbs RPM psi DEPTH: 8635/ 8062ìVD 9 YP 19 FL TR OIL 0.25 MBL Gels pH 10/19/20 9.0 CL- Ca+ 40 8.9 PV SD 7.2 5.75 31000 80 CCI MWD SUMMARY INTERVAL TO TOOLS ( 3AS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE 282 @ 8311 10 @ 8254 47.1 TRIP GAS= @ @ WIPER GAS= CHROMA TOGRAPHY(ppm) SU RVEY= 54548 @ 8311 1866 @ 8254 9323.1 CONNECTION GAS HIGH= 90 @ 8311 @ 14.1 AVG= 34 @ 8311 @ 5.8 CURRENT @ @ CURRENT BACKGROUND/AVG 18/35 @ @ NONE LITHOLOGY/REMARKS GAS DESCRIPTION METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL Major Sand/Sandstone, Coal, Tuffaceous Claystone, Tuffaceous Siltstone, Minor Volcanic Ash, Tuffaceous Shale, Carvbonaceous Shale. Very Minor Conglomeratic Sand. LITHOLOGY PRESENT LITHOLOGY SAND/SANDSTONE, COAL, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Drill from 7949' to report depth. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 14,2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 8 6.75" { ( DAILY WELLSITE REPORT 6 EPOCH PRESENT OPERATION= PULLING OUT OF HOLE DEPTH 8900 YESTERDAY 8638 24 Hour Footage 262 DEPTH 8586 8835 8900 (Projected) INCLINATION 1.10 2.30 2.30 AZIMUTH 291 .60 310.80 310.80 TYPE STC XR20TDGPS SIN LY9537 JETS 3 x 13 INTERVAL IN OUT 7815 8900 FOOTAGE 1085 HOURS 31.47 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.25 VIS FC 2 SOL MWD SUMMARY INTERVAL TO ( "OOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS M ETHAN E(C-1) ETHAN E(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 202,7 @ 8706 11.7 @ 8899 51.8 @ @ 23 @ 8767 6 @ 8887 16.4 @ @ 2642 @ 8814 2247 @ 8893 2501,3 DEPTH: 8900 I 8327TVD 45 PV 10 YP 20 FL 8.0 Gels 8.0 SO TR OIL 0.25 MBL 5.5 pH 12/18/25 9.0 VERTICAL DEPTH 8013.14 8262.03 8326.98 CONDITION REASON TIBIC PULLED In Hole TD CURRENT AVG 27.6 fVhr amps 19.9 Klbs RPM 2473 psi CL- 32000 80 CCI Ca+ HIGH LOW AVERAGE 681 @ 8713 12 @ 8838 118.8 TRIP GAS= @ @ WIPER GAS= 255 CHROMATOGRAPHY(ppm) SU RVEY= 136002 @ 8713 2551 @ 8838 23720.2 CONNECTION GAS HIGH= 194 @ 8713 3 @ 8840 34.2 AVG= 108 @ 8709 @ 20.1 CURRENT 45 @ 8713 @ 3.0 CURRENT BACKGROUND/AVG 12/115 @ @ LITHOLOGY IREMARKS GAS DESCRIPTION Major Sand/Sandstone, Tuffaceous Claystone, Coal, Tuffaceous Siltstone. Minor Volcanic Ash, Carbonaceous Shale, Tuffaceous Shale. Very Minor to Trace Conglomeratic Sand. LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY SAND/SANDSTONE, COAL, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE Drill from 8638' to 8900', CBU. Pump 46bbl hi-vis sweep. Circulate sweep around. Circulate and condition. Pump dry job, POOH to window. Service rig. RIH. Circulate around hi-vis sweep. Circulate and condition. Pump dry job. POOH. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva l \ MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 15, 2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE 8 6.75" TYPE STC XR20TDGPS SIN L Y9537 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS 42 PV FC 2 SOL 8.0 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH l JITCH GAS N/A \ CUTIING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY N/A PRESENT LITHOLOGY N/A ~.. DAILY WELLSITE REPORT (" g EPOCH DEPTH 8900 YESTERDAY 8900 PRESENT OPERATION= TESTING BOPE 24 Hour Footage 0 INCLINATION AZIMUTH HOURS 31.47 Gels pH VERTICAL DEPTH CONDITION T/B/C 3-3-BT-G-E-1-ER-TD REASON PULLED TD JETS 3 x 13 INTERVAL IN OUT 7815 8900 FOOTAGE 1085 CURRENT AVG 12/18/21 8.5 ftlh r amps Klbs RPM psi CL- 32000 Ca+ 80 CCI HIGH LOW AVERAGE N/A @ @ @ @ @ @ @ @ @ @ DEPTH: 8900 18327TVD 10 YP 18 FL TR OIL 0,25 MBL 8.4 5.5 TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ N/A LITHOLOGY/REMARKS DAILY ACTIVITY POOH with 4" drill pipe and BHA. Lay down MWD and mudmotor, Hold PJSM with Schlumberger. Rig up to run wireline logs. Wireline logging run SUMMARY #1 with Platform Express (AIT+H - DSI - TLD - CNL) tools. Wireline logging run #2 with RFT-GR tools. Rig down Schlumberger, Pull wear ring. Rig up and test BOPE. Epoch Personel On Board= 4 Daily Cost 2677 Report by: Craig Silva ( MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD ( REPORT FOR JERRY LORENZEN DATE Aug 16,2001 TIME 24:00 CASING INFORMATION 95/8" @ 3094' SURVEY DATA BIT INFORMATION NO. SIZE 8RR 6.75" TYPE STC XR20TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 2 SOL 43 8,25 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 LITHOLOGY NM PRESENT LITHOLOGY N/A { DAILY WELLSITE REPORT g EPOCH DEPTH 8900 YESTERDAY 8900 PRESENT OPERATION= LAYING DOWN DRILL PIPE 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH CONDITION T/B/C 3-3-BT -G-E-1-ER- TD REASON PULLED Prep for Casing INTERVAL SIN JETS IN OUT FOOTAGE HOURS L Y 9537 3 x 13 8900 8900 0 3.16 HIGH LOW AVERAGE N/A @ @ @ @ @ @ @ @ @ @ PV SD DEPTH: 8900/ 8327ìVD 10 YP 20 TR OIL 0.25 8.5 6.5 CURRENT AVG ftIhr amps Klbs RPM psi Gels pH 1 0/21 8,5 CL- Ca+ 32000 80 CCI FL MBL 265 HIGH LOW @ 8900 12 @ 8900 @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ AVERAGE 125 TRI P GAS= 265 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 12/125 GAS DESCRIPTION N/A LITHOLOGY/REMARKS DAILY ACTIVITY SUMMARY Continue testing BOPE. Install wear bushing. Make BHA. RIH to 8900'. CBU. Pump 46bbl Hi Vis sweep. Drop Gyro and pump to bottom, Pump dry job. POOH laying down drill pipe and BHA, Survey at 93' intervals. Lay down drill pipe from derrick. Clear rig floor and pepare to run 4 1/2" casing. EpoCh Personel On Board= 2 Daily Cost 1883 Report by: Craig Silva ( .( DAILY WELLSITE REPORT MARATHON OIL COMPANY FALLS CREEK UNIT NO.1 RD (' REPORT FOR JERRY LORENZEN DATE Aug 17, 2001 TIME 24:00 (' U EPOCH DEPTH 8900 YESTERDAY 8900 PRESENT OPERATION= CEMENTING 4 1/2" CASING 24 Hour Footage 0 SURVEY DATA CASING INFORMATION 95/8" @ 3094' 4 1/2" @ 8894' DEPTH AZIMUTH BIT INFORMATION NO. SIZE N/A DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS FC 2 SOL MWD SUMMARY INTERVAL TO TOOLS ( GAS SUMMARY(units) JITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY N/A PRESENT LITHOLOGY N/A INCLINATION TYPE INTERVAL SIN JETS IN OUT FOOTAGE HOURS HIGH LOW AVERAGE N/A @ @ @ @ @ @ @ @ @ @ DEPTH: 8900 / 8327TVD 43 PV 9 YP 16 FL 10,0 Gels 9.0 SD 0.25 OIL 0.25 MBL 7.5 pH VERTICAL DEPTH CONDITION T/B/C REASON PULLED 263 HIGH LOW @ 8894 6 @ 8894 @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ AVERAGE 12 CURRENT AVG ftlhr amps Klbs RPM psi 12/24/24 9.5 CL- Ca+ 21000 120 CCI N/A LITHOLOGY/REMARKS TRIP GAS= 263 WIPER GAS= SU RVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 6/12 GAS DESCRIPTION Install 4 1/2" buttress crossover on floor safety valve. Change rams from 4" to 41/2", Change out bails and elevators. RIH with 41/2" (12.6 Ib/ft) DAILY buttress casing, Fill pipe and circulate at 3110', Continue RIH with casing. Land casing in hanger. (Note chemical injection mandrel at 1950', float ACTIVITY collar at 8849', and shoe at 8894'), Begin rigging up BJ cementers. Rig up cement head and circulate, Condition hole. Hold PJSM for cementing SUMMARY procedures. Load head. Test lines to 3000psi. Pump spacer (40bbls, 9%KCL), lead slurry (150bbls, 12,5ppg, 405 sacks class "G" cement) and tail slurry (130bbls, 15.7ppg, 647 sacks), Drop plug. Displace (134,5bbls, 4%KCL), Bump plug. Hold at 3000psi. Rig down BJ cementers. Epoch Personel On Board= 2 Daily Cost 1883 Report by: Craig Silva (