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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Pull Cap String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7910 feet 6937 feet true vertical 6047 feet N/A feet Effective Depth measured 6937 feet N/A feet true vertical 5165 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)Cap String 3/8" 2205 Stainless Steel 5,075' MD 3,473' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 486 Water-Bbl MD 101' 1,840' 33 Oil-Bbl measured true vertical Packer 3-1/2"7,866' 3,302' 6,008' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik / Beluga-Tyonek GasN/A measured TVD Tubing Pressure 12436 Ninilchik Unit Falls Ck 4 N/A ADL0000590, FEE-PRIVATE 4,888' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-221 50-133-20533-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 113 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 513 0 Representative Daily Average Production or Injection Data 84' 1,823' 4,871' 7,849' Conductor Surface Intermediate Production 10,540psi Casing Structural 20" 13-3/8" 9-5/8" Length 6,330psi 3,450psi Collapse 770psi 1,950psi 3,810psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,410psi 10,160psi 101' 1,550' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:48 pm, Jul 31, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.07.31 13:06:02 -08'00' Taylor Wellman SFD 7/31/2020 run gls 9/2/20 DSR-8/3/2020 RBDMS HEW 8/3/2020 Rig Start Date End Date Cap String 7/4/20 7/4/20 07/04/2020 - Saturday Re-ran CAP string to 5,075'. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Ninilchik Unit Falls Ck 4 50-133-20533-00-00 201-221 MD TVD 5,526' 3,882.1' 5,580' 3,931.0' 5,842' 4,168.7' 5,932' 4,250.6' 6,038' 4,347.1' 6,446' 4,717.9' 6,674' 4,925.1' 7,310' 5,503.7' 7,654' 5,816.1' Bottom of Perfs Tree cnx = 4-3/4" Otis TD 7,910' MD 6,047' TVD Excape System Details: - 9 Excape modules placed -Red contol line fires top 8 modules -Green control line fires bottom 1 module - Ceramic flapper valves below each module except for Module 1 Perfs MD (RKB): Module 9 - 5,516' - 5,526' Module 8 - 5,570' - 5,580' Module 7 - 5,832' - 5,842' Module 6 - 5,922' - 5,932' Module 5 - 6,028' - 6,038' Module 4 - 6,436' - 6,446' Module 3 - 6,664' - 6,674' Cement Plug @ 6,937' 3-1/2" CIBP @ 6,974' Module 2 - 7,300' - 7,310' Module 1 - 7,644' - 7,654' Top of Cement (est.) @ 4,588' MD (300' above 9-5/8" shoe) Excape System Details: - BHP monitoring line volume tank located from 5,435' - 5,471' Excape System Details: - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 5,543' Module 8 - 5,596' Module 7 - 5,857' Module 6 - 5,947' Module 5 - 6,054' Module 4 - 6,462' Module 3 - 6,689' Module 2 - 7,327' Module 1 - NA Beluga Perfs MD (RKB): MD Footage TVD 5084-5094’ 10 ft 3472-3490’ 2-3/8", 4 SPF (11/11/05) 15' Owen Patch (5,081'-5,097.5') 2.375" ID (8/7/08) 5204-5208’ 4 ft 3590-3594’ 2-3/8", 4 SPF (11/11/05) 5316-5329’ 13 ft 3692-3704’ 2-3/8", 4 SPF (11/11/05) 21' Owen Patch (5,312'-5,333') 2.375" ID (8/1/08) 5360-5376’ 16 ft 3732-3746’ 2-3/8", 4 SPF (11/10/05) 5383-5416’ 33 ft 3753-3783’ 2-3/8", 4 SPF (11/10/05) 5465-5478’ 13 ft 3827-3839’ 2-3/8", 4 SPF (11/9/05) 3-1/2" CIBP @ 6,974' 37' of cement on top of CIBP (7/23/08) FCU - 4 Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1N, R12W, S.M.Permit #:203-221 API #:50-133-20533-00-00 Prop. Des:ADL - 590 KB elevation:262' (17' AGL) Latitude: Longitude: Spud:1/20/2004 TD:2/4/2004 Rig Released: PBTD 6,937' MD 5,165' TVD Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 101' TVD 0' 101' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,840' TVD 0' 1,550' 16" hole Cmt w/ 434 sks of 12.5 ppg, Class G Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 4,888' TVD 0' 3,302' 12-1/4" hole Cmt w/ 400 sks of 12.5 ppg, Class G, Lead & 175 sks of 13.5 ppg, Class G, Tail Production Casing 3-1/2" L-80 9.3 ppf EUE Top Bottom 8rd MD 0' 7,866' TVD 0' 6,008' 8-1/2" hole Cmt w/ 850 sks of 13.5 ppg, Class G Capillary String 07/04/20 3/8” 2205 Stainless Steel Top Bottom MD 0’ 5,075' TVD 0’ 3,473' Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Falls Creek #4 Kenai Peninsula Borough 5,204' - 7,654' 2϶ / 100 ft @ 200' MD 3/26/2004 Donna Ambruz Lease: State: Perf (TVD): Ninilchik Unit Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 3,592' - 5,816' 25϶ RKB:245' (AMSL)17' (AGL) 07-10-20 Pollard tag fill @ 6690' kb (9/21/11) SCHEMATIC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FRIG' CEIVE® JUL 0 9 2019 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate L Pull Tubing Li Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install Cap String ❑� 2. Operator 4. Well Class Before Work:5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 203-221 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20533-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0000590, FEE -PRIVATE Ninilchik Unit Falls Ck 4 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik / Beluga-Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 7910 feet Plugs measured 6937 feet true vertical 6047 feet Junk measured N/A feet Effective Depth measured 6937 feet Packer measured N/A feet true vertical 5165 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 101' 101' 2,410psi 770psi Surface 1,823' 13-3/8" 1,840' 1,550' 3,450psi 1,950psi Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330psi 3,810psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160psi 10,540psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3/8" Cap String 2205 Stainless Steel 7,866'MD 6.645'TVD Packers and SSSV (type, measured and true vertical depth) N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation: 0 908 16 14 1 114 Subsequent to operation: 0 697 24 14 1122 14. Attachments (required Per 20 nnc 25.070, 25.07(, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory[] Development Service ❑ Stratigraphic [] Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas L4J WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-085 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: 09_07�.com Authorized Signature.'/ ! c Date: Contact Phone: 777-8420 Form 10-404Revised a/zon/n/ lie � RBDMS�U� 10 2018 Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Ninilchik Unit Falls Ck 4 Cap String 1 50-133-20533-00 1 201-221 6/12/19 6/12/19 Daily Operations: 06/12/2018- Wednesday 5:30 Pickup tools at PWL shop Then Travel to Susan Dionne. 6:45 Arrive at Susan Dionne, do Permit and Safety Briefing -Travel to Falls Creek. / 7:15 Arrive at Falls Creek Check Unit Fluids Start and Spot Equipment. ✓ Rig up unit, pick old Cap String off truck and Set aside, pick new Spool and Set up on truck. Pickup up injector head 9:30 M/U Foot Valve Set for 2,205 psi- test on surface, opening at 3,100 psi, inform Hilcorp Rep, try 4 other valves on the Truck all Opening higher pressures, have issues with Triplex on Dynacoil unit, Temp fix. 12:30 Stab on well Standby for Fluid to P/T Packoff Head then Test 250 low 2,500 high, GOOD. 14:30 RIH/w BHA to 750' Stop. Injector Head chain Drive on one side had slipped to the side P/U manlift and 15:30 Set Anchor to Free up Skate on Injector head, Pry back into position then Retighten Screws. Rebite with Skate set at Higher Pressure to Keep tight enough to have less slippage 17:00. Pull Anchor and Continue into hole to 2,830' RKB start seeing weight loss due to Deviation have to slow down considerably to watch weight to 4,850' RKB, pickup to 4,800' RKB (pickup weight of 1,350) test Foot valve down hole still opening Around 3,000 PSI. 18:00 Set Anchor and Rig off Dyna Coil. Clean and Secure area and Equipment Park on Edge of Pad (picked old Spool Back onto Truck). H Hilcorp Alaska 203-221 50-133-20533-00-00 ADL - 590 262' (17'AGL) 2/4/2004 Tree cnx = 4-3/4" Otis Top of Cement (est.) @ 4,588' MD (300' above 9518" shoe) Capillary String 06/12/19 318" 22055fainleu Steel Top Bottom MD 0' 4,800' ND 0' 3.223' located from 5,435'- 5,471' Pollard tag fill @ 6690' kb (9/21/11) 3-1/2" CIBP @ 6,974' 37' of cement on top of CIBP (7/23/08) - Ceramic flapper valves below each module as follows: Module 8 - 5,596' Module 7 - 5,857' Module 6 - 5,947' Module 5 - 6,054' Module 4 - 6,462' Module 3 - 6,689' Module 2 - 7,327' Module 1 - NA FCU -4 Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1N, R12W, S.M. TD PBTD 7,910' MD 6,937' MD 6,047' ND 5,165' ND SCHEMATIC Conductor 20" K-55 133 ppf PE Too ott MD 0' 101' ND 0' 101' 133/8" K45 68 ppf BTC 129 soft.. MD 0' 1,840' ND 0' 1,550' 16" hole Cmt w/ 434 sks of 12.5 ppg, Class G Intermediate Casing 9-5/8" L-80 47 ppf BTC 148 Bottom MD 0' 4,888' ND 0' 3,302' 12414" hole Can w/ 400 sks of 12.5 ppg, Class G, Lead & 175 sks of 13.5 ppg, Class G, Tail Production Ca,una 3-1/2" L-80 9.3 ppf EUE T -P Bottom 8rd MD 0' 7,866' TvD 0' 6,008- 8-112- hole Cmt w/ 850 sks of 13.5 ppg, Class G MD Footase TVD 15' Owen Patch (5,081'-5,097.5') 2.375" ID 5208' 4 ft 3590-3594' 2-318",4 SPF 21' Owen Patch (5,312'-5,333') 2.375" ID (811/08) 5376' 16 k 3732-3746' 2-3/8", 4 SPF (11/10105) 5416' 33 ft 3753-3783' 2-3/8",4 SPF (11110105) 5478' 13 ft 3827-3839' 2-318", 4 SPF (11/9/05) - 9 Excape modules placed - Red contol line fres tap 8 modules - Green control line fires bottom 1 module - Ceramic flapper valves below each module except for Module 1 Module 9 - 5,516'- 5,526' Module 8 - 5,570'. 5,580' Module 7 - 5,832'- 5,842' Module 6 - 5,922'- 5,932' Module 5 - 6,028'- 6,038' Module 4 - 6,436'- 6,446' Module 3 - 6,664'- 6,674' Cement Plug @ 6,937' 3-112" CIBP @ 6,974' Module 2 -7,300'.7,310' Module 1 - 7,644'- 7,654' Bottom of Perfs MD TVD 5,526' 3,882.1' 5,580' 3,931.0- 5,842' 4,168.7- 5,932' 4,250.6- 6.038' 4,347.1' 6,446' 4,717.9- 6,674' 4,925.1' 7,310' 5,503.7' 7,654' 1 5,816.1' Well Name & Number: Falls Creek #4 Lease: Ninilchik Unit Municipality: Kenai Peninsula Borough State: Alaska I Country: USA Perforations MD: 51204'-7,654' Perf TVD: 3,592'-5,816' Angle @ KOP & Depth: 20 / 100 ft @ 200' MD Angle @ Perfs: 250 Date Completed: 3/26/2004 Ground Level: 245' AMSL RKB: 17' AGL Revised by: Donna Ambruz Revision Date: 07.05-19 • v,OF Tye • • �; .��yyy�s., THE STATE Alaska Oil and Gas 41,,„......,--- ,.....Z4 ofA LAsKA Conservation Commission F . .w y� a 0 l 1 It th 333 West Seventh Avenue " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �' .,` Main: 907.279.1433 OF ALA *� Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager wtiej ,. I 4- 1. Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Ninilchik Field, Beluga-Tyonek Gas Pool,NU FCK 4 Permit to Drill Number: 203-221 Sundry Number: 318-085 Dear Mr. Helgeson: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 611X4c Hollis S. French -- Chair DATED this fo day of March,2018. RP S P-- M r, 2618 • 0 • RECEIVED STATE OF ALASKA FEB 2 8 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION 0:77 3l6/ /Ft APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well p 0 Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: Install Cap String 0- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development Q- 203-221 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20533-00- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ❑ Ninilchik Unit Falls Ck 4 Will planned perforations require a spacing exception? Yes 0 No 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0000590 Kyr__ -?r v'4,4-. Ninilchik/Beluga-Tyonek Gas 11. 3,Z.:/v PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,910' ' 6,047' - 6,947 5,165' -1,530 psi 6,937 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 101' 101' 2,410psi 770P si Surface 1,823' 13-3/8" 1,840' 1,550' 3,450psi 1,950P si Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330psi 3,810psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160psi 10,540psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size:3-1/2"Excape Tubing Grade: L-80 Tubing MD(ft): 7,866' See Attached Schematic See Attached Schematic 3/8"Cap String 2205 Stainless Steel 6,645' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A; N/A N/A; N/A 12.Attachments: Proposal Summary El Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: March 14,2018 OIL ❑ WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS Q WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramert hilcorp.com Contact Phone: 777-8420 Authorized Signature: C/,, ,--74',..- Date: Z-/? /(R COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1<6- UZ'S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 �iE` ` ✓ ''"i i��8 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: IU — YD4-I APPROVED BY I �p Approved by: LOC) g\------- //COMMISSIONER THE COMMISSION Date: 3 b li V , ove�� Rd 1 3.z., a it Form and Form 10-403 Revised 4/2017 Approved applicati o date of approval.41* Attachments in Duplicate . n • I Well Prognosis Well: Falls Creek#4 Ililcorp Alaska,LL) Date:02/26/2018 Well Name: Falls Creek#4 API Number: 50-133-20533-00-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: March 14, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-221 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) AFE Number: Current Surface Pressure: —675 psi @ Surf. From September 2017-5 day press. Buildup. Maximum Expected BHP: — 1,700 psi @ 5,816' TVD (Calc. Assuming Half column of water) Max. Potential Surface Pressure: — 1,530 psi (Assuming 0.1 psi/ft Gas gradient) Brief Well Summary The Falls Creek#4 well was drilled in February of 2004 and completed with an Excape System in March of that year. In November of 2005 Beluga perforations were added.This well is deviated at over 63 degrees from 1,837 feet to 3,339' before dropping off to 25 degrees at TD. This well has a water loading problem which has been handled to date by dropping soap sticks. v The purpose of this work/sundry is to install a cap string to continuously inject soap to help unload water. .7 Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. Install new wellhead packoff. 3. PU 3/8" capillary string. RIH and set at+/-4,800'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic FCU - 4 SCHEMATIC Hitcorp Alaska Ninilchik Unit 1842' FSL, 2842' FWL, Conductor Permit#: 203-221 Sec. 6, T1 N, R12W, S.M. 20" K-55 133 ppf PE Top Bottom API#: 50-133-20533-00-00 MD 0' 101' Prop,Des: ADL-590 TVD 0' 101' KB elevation: 262' (17'AGL) E. " tr:Latitude: l �'� Surface Casing Longitude: 13-3/8" K-55 68 ppf BTC Spud: 1/20/2004 Top Bottom TD: 2/4/2004 .liii , MD 0' 1,840' Riq Released: TVD 0' 1,550' 16"hole Cmt w/434 sks of 12.5 ppg, Class G Intermediate Casing Tree cnx=4-3/4"Otis "( 9-5/8" L-80 47 ppf BTC ""s , T� MD 0' Bottom :* j rr 4,888' TVD 0' 3,302' Top of Cement(est.) Ink. I12-1/4"hole Cmt wl400 sks of 12.5 ppg,Class @ 4,588'MD G,Lead&175 sks of 13.5 ppg,Class G,Tail 11 (300'above 9-5/8"shoe) Production Casing `, 3-1/2" L-80 9.3 ppf EUE Top Bottom 8rd € i MD 0' 7,866' TVD 0' 6,008' 8-1/2"hole Cmt w/850 sks of 13.5 ppg,Class G 1 1. Beluga Perfs MD(RKB): i r- = MD Footage TVD --- ! ,a- 5084-5091' 10 ft -3472-34.90=2-3/8;-4-SPF(11/11105) 15'Owen Patch(5,081'-5,097.5') 2.375"ID (8/7/08) 5204-5208' 4 ft 3590-3594' 2-3/8",4 SPF(11/11/05) i 53-1-6-5-32-9 --13-ft-' - 3692 3704' 2 3/8",4 SPF(11/11/05) Excape System Details: / 21'Owen Patch (5,312'-5,333') 2.375"ID (8/1/08) BHP monitoring line volume tank 5360-5376' 16 ft 3732-3746' 2-3/8",4 SPF(11/10/05) located from 5,435'-5,471' t' 5383-5416' 33 ft 3753-3783' 2-3/8",4 SPF(11/10/05) x' 5465-5478'- 13 ft 3827-3839' 2-3/8",4 SPF (11/9/05) i . Pollard tag fill @ 6690' kb (9/21/11) I ' p �3' * Excape System Details: 9 Excape modules placed 3-1/2" CIBP @ 6,974' ** - contol line fires top 8 modules f•"; -Green control line fires bottom 1 module 37' of cement on top of CIBP ~ t -Ceramic flapper valves below each (7/23/08) ,i I module except for Module 1 IIS ` Perfs MD(RKB): Bottom of Perfs Excape System Details: Module 9-5,516'-5,526' Ceramic flapper valves below Module 8-5,570'-5,580' - MD TVD each module as follows: 1,1, ' ' Module 7-5,832'-5,842' 5,526' 3,882.1' r` '� Module 6-5,922'-5,932' Flappers MD(RKB): Module 5-6,028'-6,038' • 5,580' 3,931.0' Module 9-5,543' Module 4-6,436'-6,446' 5,842' 4,168.7' Module 8-5,596' Module 3-6,664'-6,674' - 5,932' 4,250.6' Module 7-5,857' Cement Plug @ 6,937' Module 6-5,947' I, 6,038' 4,347.1' 3-1/2"CIBP @ 6,974' Module 5 6,054' Module 2-7,300'-7,310' 6,446' 4,717.9' Module 4-6,462' Module 1 -7,644'-7,654' 6,674' 4,925.1' Module 3-6,689' Module 2-7,327' 7,310' 5,503.7' Module 1 - NA TD PBTD 7,654' 5,816.1' 7,910'MD 6,937'MD 6,047'TVD 5,165'TVD Well Name& Number: Falls Creek#4 Lease: Ninilchik Unit Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,204'-7,654' Perf(TVD): 3,592'-5,816' Angle @ KOP & Depth: 2°/100 ft @ 200'MD Angle @ Perfs: 25° Date Completed: 3/26/2004 Ground Level: 245' (AMSL) RKB: 17' (AGL) Revised by: Donna Ambruz Revision Date: 02-27-18 • II FCU - 4 ROPOSED xiiec>`rpAlaska Ninilchik Unit SCHEMATIC 1842' FSL, 2842' FWL, Conductor Permit#: 203-221 Sec. 6, T1 N, R12W, S.M. 20" K-55 133 ppf PE Top Bottom API#: 50-133-20533-00-00 MD 0' 101' Prop.Des: ADL-590 KB elevation: 262' (17'AGL) t L,'. TVD 0' 101' Latitude: " 6r Longitude: .' a Surface Casing 13-3/8" K-55 68 ppf BTC Spud: 1/20/2004 « . • ,� Top Bottom TD: 2/4/2004 f� ;� r MD 0' 1,840' Rig Released: r TVD 0' 1,550' t. 16"hole Cmt w/434 sks of 12.5 ppg, Class G loN s.d i.*, ` Intermediate Casing Tree cnx=4-314 Otis -"'! 9-5/8" L-80 47 ppf BTC Top Bottom ' MD 0' 4,888' TVD 0' 3,302' Top of Cement(est) - �. +i., 12-1/4"hole Cmt w1400 sks of 12.5 ppg,Class @ 4,588'MD r G,Lead&175 sks of 13.5 ppg,Class G,Tail (300'above 9-5/8"shoe) Production Casing 3-1/2" L-80 9.3 ppf EUE Capillary String Proposed to Install Top Bottom 8rd 7,866' MD 0' Bottom 3/8" 2205 Stainless Steel /- x TVD 0' 6,008' Top Bottom ,_ 8-1/2"hole Cmt w/850 sks of 13.5 ppg,Class G MD 0' X,XXX' .IB TVD 0' X,XXX' gg 1 _ I 1 1 1 . r Beluga Peas MD(RKB): tis MD Footage WD Excape System Details: -BHP monitoring line volume tank i a' !94' 10 ft !' :" /41/05) located from 5,435'-5,471' `+ 15'Owen Patch(5,081'-5,097.5') 2.375"ID (8/7/08) 5204-5208' 4 ft 3590-3594' 2-3/8",4 SPF(11/11/05) 21'Owen Patch (5,312'-5,333') 2.375"ID (8/1/08) Pollard tag fill @ 6690' kb 5360-5376' 16 ft 3732-3746' 2-3/8",4 SPF(11/10/05) (9/21/11) J i 5383-5416' 33 ft 3753-3783' 2-3/8",4 SPF(11/10/05) 5465-5478' 13 ft 3827-3839' 2-3/8",4 SPF (11/9/05) ::.? I f ' 3-1/2" CIBP @ 6,974' Excape System Details: 37' of cement on top of CIBP , 9 Excape modules placed (7/23/08) ,, -; - contol line fires top 8 modules 1,,:: -Green control line fires bottom 1 module Bottom of Perfs Excape System Details: C( S -Ceramic flapper valves below each -Ceramic flapper valves below module except for Module 1 MD TVD each module as follows: 1 '- +y' Perfs MD(RKB): 5,526' 3,882.1' Flappers MD(RKB): ) Module 9-5,516'-5,526' 5,580' 3,931.0' Module 9-5,543' Module 8-5,570'-5,580' 5,842' 4,168.7' Module 8-5,596' Module 7-5,832'-5,842' Module 7-5,857' Module 6-5,922'-5,932' 5,932' 4,250.6' Module 6-5,947' Module 5-6,028'-6,038' 6,038' 4,347.1' Module 5-6,054' Module 4-6,436'-6,446' 6,446' 4,717.9' Module 4-6,462' Module 3-6,664'-6,674' Module 3-6,689' Cement Plug @ 6,937' 6,674' 4,925.1' Module 2-7,327' 3-1/2CIBP @ 6,974' 7,310' 5,503.7' Module 1 - NA TD PBTD Module 2-7,300'-7,310' 7,654' 5,816.1' Module 1 -7,644'-7,654' 7,910'MD 6,937'MD 6,047'TVD 5,165'TVD Well Name& Number: Falls Creek#4 Lease: Ninilchik Unit Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,204'-7,654' Perf(TVD): 3,592'-5,816' Angle @ KOP& Depth: 20/100 ft @ 200'MD Angle @ Perfs: 25° Date Completed: 3/26/2004 Ground Level: 245' (AMSL) RKB: 17'(AGL) Revised by: Donna Ambruz Revision Date: 07-21-17 e e Image Project Well History File Cover 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 by direct inspection of the file. ~ 0 3 - ~ ~ J Well History File Identifier Organizing (done) D Two-sided ""1111111111" 11/ D Rescan Needed 1111111111111 11111I RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, Norrype: D Poor Quality Originals: NOTES: Date 5/ ðlO~ I OVERSIZED (Non-Scannable) ~9S of various kinds: D Other:: D Other: BY: ~ Isl llif DaleÓ/ðJo(p I /¡; 11111111111111 "III f\tf Project Proofing BY: ~ Isl Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: d og (Count does include cover sheet) Page Count Matches Number in Sc nning Preparation: ~ES BY ~ Dale 13/0~ Stage 1 If NO in stage 1, page(s) discrepan ies were found: YES 11111111111111 "III NO VV1f Isl NO BY: Maria Date: Isl 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: Isl Comments about this file: Quality Checked 11111111I111 "11111 10/6/2005 Well History File Cover Page.doc Alaska Production LLC• • + i Ail Marathon 1.._�l. P. Asset Team Marathon Oil P.O. . Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 5, 2012 Mr. Daniel Seamount �� Alaska Oil & Gas Conservation Commission 333 W 7 Ave JAN Anchorage, Alaska 99501 (lai Gas Cons, Con SStOn Reference: 10 -404 Report of Sundry Well Operations . tastxa Field: Ninilchik Unit as 3 ag-1. Well: Falls Creek #4 Dear Mr. Seamount: Attached for your records is the Report of Sundry Well Operations, 10 -404, for FC -4 well. This report covers the work performed to raise the capillary string up -hole 20 feet. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, a _ S tAlOPED JAN 2 5 2012 W � 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 (2) KJS RECEIVED STATE OF ALASKA JAN 0 9AMAL AND GAS CONSERVATION COMMISSil, //��°� REPORT OF SUNDRY WELL OPERATIONS links Oit & Gas Cons. Commission 1. Operations Abandon LtilnA Well H Plug Perforations LJ Stimulate H Other U Raise Cap- String 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 Alaska Production LLC Development Q Exploratory [1 203 - 221 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: AoSili rAht Kenai Alaska, 99611 1949 50 133=09940;00 - 00 9 7. Property Designation (Lease Number): - 8. Well Name and Number: ADL - 00590 0 Falls Creek #4 9. Field /Pool(s): Ninilchik Unit / Beluga & Tyonek Pools 10. Present Well Condition Summary: Total Depth measured 7,910' feet Plugs measured 6,937' feet true vertical 6,047' feet Junk measured NA feet Effective Depth measured 7,829' feet Packer measured NA feet true vertical 5,974' feet true vertical NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 101' 101' 2,410 psi 770 psi Surface 1,823' 13 -3/8" 1,840' 1,550' 3,450 psi 1,950 psi Intermediate 4,871' 9 -5/8" 4,888' 3,302' 6,330 psi 3,810 psi Production 7,849' 3 -1/2" 7,866' 6,008' 10,160 psi 10,540 psi Liner psi psi Perforation depth: Measured depth: 5,204'- 6,446' feet True Vertical depth: 3,594'- 5,718' feet Excape 3 -1/2" L -80 7,866' MD 6,008' TVD Tubing (size, grade, MD & TVD): Capillary String 3/8" 2205 Stainless Steel 6,645' MD 4,899' 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): Capillary string was raised up -hole 20' and reset at 6,645' 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 43 0 810 Subsequent to operation: 0 1,240 21 0 307 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 i Service ❑ - Stratigraphic El Daily Report of Well Operations X 15. Well Status after work: Oil LJ Gas U WDSPL u GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: NA Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba aR.,- Title R egulatory Compliance Representative Signature em u,,. 4 . Phone (907) 283 -1371 Date January 5, 2012 'L I JAN 0 9 1012 Form 10 -404 Revised 10/2010 kIlLO Submit Original Only *rations Summary Report by Job • Marathon Oil Well Name: FALLS CREEK 4 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country NINILCHIK FALLS CREEK ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) I KB- Ground Distance (m) Spud Date Rig Release Date 0.00 74.68 79.711 5.03 1/20/2004 Daily Operations Report Date: 9/21/2011 Job Category: R &M MAINTENANCE 24 Hr Summary Trouble with Cap String, Showing 60 -80psi at surface while pumping, recent Foam over run episode at facilities. Pulling Cap String and FCV for inspection. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 07:00 07:30 0.50 SAFETY MTG Held Safety Meeting, discussed pulling well house and cap string. Review JSA's 07:30 08:30 1.00 PULL EQIP Lift Wellhouse 08:30 10:30 2.00 RURD COIL Rig Up BJ Cap String Unit, lay down pit liner, pickup spool onto truck, pick up and prepare injector head 10:30 12:30 2.00 RUNPUL COIL Release Slips, Pick up Coil, Initial unland weight 18001b's, Pull 6665ft of 3 /8in cap string from well. Aproximatly 8ft above FCV a hole was discovered. Foamer began to leak from hole as it passed through skates, operator reveresed and ran back in well to contain it. There must be a plug further up the string because the cap string had zero pressure at surface and there was no fluid at the valve. Pulled string back out of well so hole was just above packoff. Tried to let hole and string depressurize but continued to vent for 25 minutes. Pulled rest of string from hole. Shut Master, Blew down tree, Hole stopped venting gas. Unsure why FCV failed to act as check. It is being sent in for evaluation. 12:30 13:30 1.00 RURD COIL Rig Down Coil, Take failed capilary string to office for inspection and flush www.peloton.com Page 1/1 Report Printed: 1/4/2012 /t% /J *rations Summary Report by Job• ° Marathon Oil Well Name: FALLS CREEK 4 • Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country NINILCHIK FALLS CREEK ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 74.68 79.71 5.03 1/20/2004 Daily Operations Report Date: 9/22/2011 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard to tag fill and run PT Survey. Tagged fill © 6694' kb. Lowest Module is #3 6664' - 6674'. Maximum pressure @ 6690' was 960 psia and 99 degrees F. Fill appeared to be mostly white 20/40 frac sand, some coal, and gray fines. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG Hold PJSM. Discuss alarms, strobes, muster area, and emergency response. Obtain SWP. Discuss JSEA and make job assignments. Watch out for wet footing on ladders. 08:30 09:45 1.25 RURD SLIK Move over from CLU 5S. RU slickline unit, PU lubricator w/ tool string -RS, KJ, 10'x 1 -1/2" stem, KJ, OJ, LSSJ, 2 -1/2" DD bailer. Carry lubricator to WH. 09:45 10:00 0.25 TEST EQIP PTest lubricator to 2500 psi. Test good. 10:00 11:06 1.10 RUNPUL SLIK RIH(1) w/ 2 -1/2" DD Bailer. Tag fill @ 6690' kb. Work tools to 6694'. Not sticky at all. OOH. No sample recovered. 11:06 13:57 2.85 RUNPUL SLIK RIH(2) w/ Tandem PT gauges to 6690' at 120 fpm. Stop at 6690' for a 10 min bench. POOH at 120 fpm with 3 min benches @ 6000', 5500', 5000', 4000', and 2000'. Stop at 21' for 5 min bench. maximun pressure @ 6690' 960 psia and 99 degrees F. 13:57 14:42 0.75 RUNPUL SLIK RIH(3) w/ 2" DD Bailer w/ Tyler bottom. Tag fill @ 6694' kb. Work tools to 6699'. Pooh. OOH. Recovered full bailer of what appeared to be mostly white 20/40 (Ottawa) frac sand. with flakes of coal, and gray silt fines. 14:42 ' 15:27 0.75 RURD SLIK RD slickline unit. Install tree cap and PTest with well pressure to 850 psi. Tests good. 15:27 15:42 0.25 SECURE WELL Secure well and location. Turn in permit and leave loc. Lock gate. www.peloton.com Page 1/1 Report Printed: 1/4/2012 d /l. rations Summary Report by Job Marathon Oil Well Name: FALLS CREEK 4 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country NINILCHIK FALLS CREEK ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 74.68 79.71 5.03 1/20/2004 Daily Operations Report Date: 10/8/2011 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Baker DynaCoil to run capillary string to 6645'. ( FCV Sr.No. 040800110). Set FCV operating pressure to 2700 psi. Tested cap string to 3600 psi. Displace string to Faomer while RIH. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 08:45 0.75 SAFETY MTG Held Safety Meeting. Obtain SWP. Discuss alarms, muster area, and emergency response procedures. Review JSA's and make job assignments. Let's work slow and steady today so nobody gets hurt. Operations drops 2 soap sticks. 08:45 11:24 2.65 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. Clean wellhead adapter. Install new 0-ring and grease. Clean bore of OTIS tree cap. Install WH adapter. Set operating pressure of FC Valve to 2700 psi. Pressure test "new" cap string to 3600 psi. Test good. Thread coil thru side of injector assembly. Install Packoff assembly on cap string. Pull test BHA to 550 lbs. 11:24 12:00 0.60 TEST EQIP Carry injector and pack -off to WH. MU packoff. PT Hydraulic Packoff to 3000 psi. PT WH adapter to 2700 psi. Open swab valve. 12:00 14:00 2.00 RUNPUL COIL RIH to 6645' md. 14:00 15:45 1.75 RURD COIL Land cap string at 6645' md. Set Ratigun. Set mechanical slips. Set packoff pressure to 3000 psi. Walk injector down off well head. Pull tubing out the side of injector and set coil spool at WH. RD DynaCoil unit. Reconnect tubing to foamer. Pressure test foamer lines. No leaks. Prime pump and check flow rate. 15:45 16:00 0.25 SECURE WELL Secure well head. Install LOTO and signage on well valves. Turn in permit and leave loc. Notify Art w/ OPs that we have finished. Foamer rate .75 gpd and DeFoamer 1.2 gpd. i www.peloton.com Page 1/1 Report Printed: 1/4/2012 - F C - 4 • ,, 4 A #: 50- 1 3 -2 33 - 2 0 533 -00 -00 API I�l a rathon o i l PI #: 10 Prop. Des: ADL -590 Ninilchik Unit Alaska Production LLC.. KB elevation: 262' (17'AGL) 1842' FSL, 2842' FWL, Conductor Longitude: Sec. 6, T1 N, R12W, S.M. 20" K -55 133 ppf PE Spud: 1/20/2004 Top Bottom TD: 2/4/2004 MD o' 101' Rig Released: TVD o' 101' I Li Surface Casing 13 -3/8" K -55 68 ppf BTC T� Bottom MD 0' 1,840' TVD 0' 1,550' Tree cnx = 4 - 3/4" Otis 16" hole Cmt w/ 434 sks of 12.5 ppg, Class G Intermediate Casing Top of Cement (est.) 1 9 -5/8" L -80 47 ppf BTC 4,588' MD Top Bottom @ MD 0' 4,888' (300' above 9 - 5/8" shoe) TVD 0' 3,302' al 12 -1/4" hole Cmt w/ 400 sks of 12.5 ppg, Class G, Lead & 175 sks of 13.5 ppg, Class G, Tail Capillary Tubing 3/8" 2205 0.049" Stainless Steel Wall Thickness Production Casing Tog Bottom 3 -1/2" L -80 9.3 ppf EUE MD 0' 6,645' Top Bottom 8rd TVD 0' 4,899' MD 0' 7,866' (Installed 7/1/09) '_ L ••• - TVD 0' 6,008' 8 -1/2" hole Cmt w/ 850 sks of 13.5 ppg, Class G * Inspected 08/05/10 - E. * Reset FCV 09/17/1 -- * Replace FCV 08/30/11 * Remove cap string 09/20/11 _ Beluga Perfs MD (RKB): * Install /replace FCV 10 /07/11 MD Footage TVD 5084 -5094' 10 ft 3472 3490' 2 3/8 ", 4 SPF (11/11/05) 15' Owen Patch (5,081'- 5,097.5') 2.375" ID (8/7/08) Excape System Details: 5204 -5208' 4 ft 3590 -3594' 2 -3/8 ", 4 SPF (11/11/05) - BHP monitoring line volume tank ! 1 5316 5329' 13 ft 3692-3704' 2 -3/8 ", 4 SPF (11111/05) located from 5,435' - 5,471' 21' Owen Patch (5,312'- 5,333') 2.375" ID (8/1/08) 5360 -5376' 16 ft 3732 -3746' 2 -3/8 ", 4 SPF (11/10/05) i i 1,,, 5383 -5416' 33 ft 3753 -3783' 2 -3/8 ", 4 SPF (11/10/05) 5465 -5478' 13 ft 3827 -3839' 2 -3/8 ", 4 SPF (11/9/05) Pollard tag fill @ 6690' kb i ..,,s, (9/21 /11) ''' , r , '. Excape System Details: - 9 Excape modules placed 3 -112" CIBP 6,974' • @ ( w I - Red contol line fires top 8 modules 37' of cement on top of CIBP - - Green control line fires bottom 1 module (7/23/08) I { - Ceramic flapper valves below each module except for Module 1 Excape System Details: �I I+„ Perfs MD (RKB): Bottom of Perfs - Ceramic flapper valves below :o� Module 9 - 5,516' - 5,526' MD TVD , Module 8 - 5,570' - 5,580' each module as follows: j� ' / Module 7 - 5,832' - 5,842' 5,526' 3,882.1' 1�� "� Module 6 - 5,922' - 5,932' Flappers MD (RKB): 5,580' 3,931.0' Module 5 - 6,028' - 6,038' Module 9 - 5,543' 5,842' 4,168.7' Module 8 - 5,596' ' , � Module 4 - 6,436 - 6,446' Module 7 - 5,596' Module 3 - 6,664' - 6,674' 5,932' 4,250.6' Cement Plug @ 6,937' Module 6 - 5,947' 3 -1/2" CIBP @ 6,974' 6,038' 4,347.1' Module 5 - 6,054 Module 2 - 7,300' - 7,310' 6,446' 4,717.9' Module 4 - 6,462' Module 1 - 7,644' - 7,654' 6,674' 4,925.1' Module 3 - 6,689' Module 2 - 7,327' 7,310' 5,503.7' Module 1 - NA TD PBTD 7,654' 5,816.1' 7,910' MD 6,937' MD 6,047' TVD 5,165' TVD Well Name & Number: Falls Creek #4 Lease: Ninilchik Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country:] USA Perforations (MD): 5,204' - 7,654' Perf (TVD): 3,592' - 5,816' Angle @ KOP & Depth: 2 / 100 ft @ 200' MD Angle @ Perfs: 25 Date Completed: 3/26/2004 Ground Level: 245' (AMSL) RKB: 17' (AGL) Revised by: Kevin Skiba Revision Date: 1/5/12 • M Marathon MARATHON Oil Company July 6, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Ninilchik Unit Well: Falls Creek #4 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-7350 ~~~~~~G~ J~1L ~ S 2009 ~~~~~~ ~il ~ Gas Can~. ~a~mission Anchnr~~~ ~~ 3 _ ~.,~- I ' ~ ~~~:~ ~~' `I ° .N ~ ~~C1~ ~ ~ + ~ ~~ u ~ i_. Dear Mr. Aubert: Attached for your records is the Report of Sundry Well Operations, 10-404, for FC-4 well. This report covers the work performed to install the capillary string in FC-4, which was ~ approved under sundry #309-188~The string was installed on July 2"d, 2009 at a depth of 6,665' MD. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~ ~ o ..~%~ ' Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Well Schematic KJS STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS RE~E~V'I~L~~i~ ~ i~.fGA- JUL Q S 200~Orj~3`u~ 1. Operations Abandon Repair Well Plug PerForations Stimulate AS 8S~ ~~ Performed: Alter Casing ~ Pull Tubin~ Perforate New Pool ~ Waiver~ Time Extension ~~ryG~~}(a~ring ~ Change Approved Program ^ Operat. Shutdowr[] Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development Q- Exploratory~ 203-221 - 3. Address: p0 BoX 1949 Stratigraphic ~ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20533-00-00 7. KB Elevation (ft): 9. Well Name and Number: 262' ~ 17' AGL Falls Creek #4 ~ 8. Property Designation: 10. Field/Pool(s): ADL - 00590 Ninilchik Unit / Beluga and Tyonek 11. Present Well Condition Summary: Total Depth measured 7,910' _ feet Plugs (measured) NA true vertical 6,047' feet Junk (measured) NA Effective Depth measured 7,$29' feet true vertical 5,g74' • feet Casing Length Size MD ~ ND Burst Collapse Structural Conductor $4' 20" 101' 101' 2,410 psi 770 psi SurFace 1,823' 13-3/8" 1,840' 1,550' 3,450 psi 1,950 psi Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330 psi 3,810 psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 5,084'- 7,654' ~ True Vertical depth: 3,472'- 5,816' Excape Tubing 3-1/2" L-80 7,866' Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 6,665' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): A 3/8" Stainless Steel capillary string was installed at a setting depth of 6,665' MD. 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 1,300 50 0 301 Subsequent to operation: 0 850 - 0 300 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q- Service ^ Daily Report of Well Operations X 16. Well Status after work: Oi!^ Gas Q- 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: 309-188 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba . Title Regulatory Compliance Technician Signature I .~ Phone (907) 283-1371 Date July 6, 2009 V Form 10-404 Revised 04/2006 . .~ ~~,. JU~~ ~ 4 20Q9 Submit Original Only ~ • -- Marathon ~„~~, ,Qj~ Cqr~~ Operations Summary Report Well Name: FALLS CREEK 4 Re ort Date: 711RU09 Job Cate o: R&M WIAINTENANCE 24 Hr Summary Spot BJ chemicai Cap siring unit. StaR Time End Time Dur hrs O s Code Activi Code Ops Sbtus T~oubl• Code Comment 07:3D 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss JSA, assi n tasks, and issue ermit. 08:30 10:30 2.~~ RURD COIL AF Pull wellhouse. Spot unit and crane. 10:30 11:30 1.00 RURD COIL AF Start RU. Tree cap nut will not pass over wellhead adaptor. Send wellhead adaptor to machine shop. 11:30 12:~ 1.00 SECURE WELL AF Secure location for night. Re ort Date: 722009 Job Cate o: R&M MAINTENANCE 24 Hr Summary Ran 3F" cap strir~g to 6665'. Stad Tlme End Time Dur hrs 0 s Codo Activi Code Ops Status Trouble Code Comment 09:00 ~9 30 0.50 SAFETY MTG AF Hold PJSM. Discuss JSA, assign tasks, and issue ermit. 09:30 12:~ 2 50 RURD COIL AF RU dynacoil unit. Install tree adaptor remachined to 5.50D" OD. No problem. Install 3!4" BHA, flow control valve/ 1.80" bladed centralizer! 3/8" coil connector. 1200 12:15 0 25 TEST EQiP AF test between swab valve and packo 2m1900 psi. Good test. ~ 12:15 14:D0 1?5 RUNPUL COIL AF RIH 3P8" dynacoil and hang off at ,6 (top of module 3). 14:00 17:00 3.00 RURD COIL AF Rig down dynacoil unit. Replace e I house. Close permit and leave location. Electrician is scheduled to connect soap pump in AM. www.peloton.com Report Printed: 72l2009 50-133-20533-00-00 ADL - 590 ; 262' (17' AGL) 1 /20/2004 2/4/2004 'Falls Creek #4 Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1 N, R12W, S.M. I,... r r Tree cnx = 43/4" Otis Top of Cement (est.) @ 4,588' MD (300' above 9-5/8" shoe) Capillarv Tubinq 3/8" 2205 ~ 0.049" Stainless Steel Wall Thickness Top Bottom MD 0' 6,665' ND 0' 4,917' (Installed 7/1/09) 3-1/2" CIBP @ 6 974' ~ :~ . 7 r v~ ~• i% 4'~ n 4' 37' of cement on top of CIBP ~ ~~~ (7/23/08) , ~ :. - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 5,543' Module 8 - 5,596' Module 7 - 5,857' Module 6 - 5,947' Module 5 - 6,054' Module 4 - 6,462' Module 3 - 6,689' Module 2 - 7,327' Module 1 - NA y ',' ' .~, . • ~~ ~ I . ~ S~ ~ ; +~' Y~ : . ~ ~ TD PBTD 7,910' MD 6,937' MD 6,047' TVD 5,165' TVD ~ M ~n~oM Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 10'I' ND 0' 101' '13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,840' ND 0' 1,550' 16" hole Cmt w/ 434 sks of 12.5 ppg, Class G Intermediate Casinq 9-518" L-80 47 ppf BTC Top Bottom MD 0' 4,885' ND 0' 3,302' 12-1/4" hole Cmt w/ 400 sks of 12.5 ppg, Class G, Lead &'175 sks of 13.5 ppg, Class G, Tail Production Casing 3-112" L-80 9.3 ppf EUE Top Bottom 8rd MD 0' 7,866' ND 0' 6,008' 8-112" hole Cmt wl 850 sks of 13.5 ppg, Class G Footaqe ND Patched (8/7/2008) 52045208' 4 ft 3590-3594' 2-3/8", 4 SPF (11/11/2005) Patched 8/1/2008) 6' 16 ft 3732-3746' 2-318", 4 SPF (11N0/2005) 6' 33 ft 3753-3783' 2-3/8", 4 SPF (11/10/2005) 8' 13 ft 3827-3839' 2-318", 4 SPF (11/9/2005) - 9 Excape modules placed - Red contol line fires top 8 modules - Grea:; control line fires bottom 1 module - Ceramic flapper valves below each module except for Module 1 Module 9 - 5,516' - 5,526' Module 8 - 5,570' - 5,580' Module 7 - 5,832' - 5,842' Module 6 - 5,922' - 5,932' Module 5 - 6,028' - 6,038' Module 4 - 6,436' - 6,446' Module 3 - 6,664' - 6,674' Cement Plug @ 6,937' 3-1/2" CIBP @ 6,974' Module 2 - 7,300' - 7,310' Module 1 - 7,644' - 7,654' / Bottom of Perfs MD TVD 5,526' 3,882.1' 5,580' 3,931.0' 5,842' 4,168.7' 5,932' 4,250.6' 6,038' 4,347.1' 6,446' 4,717.9' 6,674' 4,925.1' 7,310' 5,503.7' 7,654' 5,816.1' Well Name: Falls Creek #4 Lease: Ninilchik Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,204' - 7,654' (TVD): 3,592' - 5,816' Angle Q KOP and Depth: 2° I 100ft ~ 200' MD Angle @ Perfs: 25° Dated Completed: 3/26/2004 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 7/2/2009 • ,~ ~ ~. _. ~ ~;, 4 s _ . F`~-" v, A 4 ~ K ! C ~. ~ ~ L $ f ~ p a ~ a_ ~ t D ~~[ ~ ° F 4 ~ , ~ ~~' h ~ ~ ~ ~~ I ~ d~ ~~ ~ ~ ~ ~ ,T_. ~. 4 ~ ~ a , , ~ ~ AL~l58iA OIL A1~ID GAS COI~TSERQATIOI~T COMl~II55IO1~T Michael D. Dammeyer Production Engineer Marathon Oil Company P.O. Box 1949 Anchorage, Alaska 996 1 1-1 949 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ~~ ~ PHONE (907) 279-1433 FAX (907) 276-7542 .~~~~ ti it, ~ ; ~t~Cr Re: Ninilchik Unit Field, Tyonek Pool, Falls Creek #4 Sundry Number: 309-188 Dear Mr. Dammeyer: aa`~~ t 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. When providing 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 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. DATED this day of June, 2009 Encl. Sincerely, • M Marathon MARATHON Oil Company May 28, 2009 Mr. Tom Maunder 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 #4 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 1CJ~ 0 ~ 2~G f~~aska Jil ~ Gas ~t~art ¢vurrrmiss6~rr Anchorage Marathon requests permission to install a 3/8" capillary string in FC-4 well to mitigate water loading. The target setting depth of the capillary string is 6,670' MD. ~ Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ..e~ll/w ` Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-403 Application for Sundry Approvals Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS MDD n, ~ U ~ • STATE OF ALASKA v~~~~~ "'~'"~~ 6 -~ -09 ALA~OIL AND GAS CONSERVATION COMMON Q ~ - ,:: APPLICATION FOR SUNDRY APPROVaOi~~ ~~~~ ~jL/z~~C~ 20 AAC 2s.2so r~~,+: x~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^ '1+'u~, a Cher ^~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String ' 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 203-221 - 3. Address: p0 BOx 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20533-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Falls Creek #4 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL - 590 ~ 262' x(17' AGL) Ninilchik Unit /Beluga and Tyonek 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,910' - 6,04T - 7,829' _ 5,974' ' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor g4' 20" 101' 101' 2,410 psi 770 psi Surface 1,823' 13-3/8" 1,840' 1,550' 3,450 psi 1,950 psi Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330 psi 3,810 psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,084'- 7,654' ~ 3,472'- 5,816' 3-1/2" L-80 7,866' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development^ ' Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: .lUne 10, 2009 Oil ^ Gas ^~ ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Michael D. Dammeyer Title Production Engineer Signature Phone Date (907) 283-1333 May 28, 2009 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: S ~L ~u~ ~ o zaos Subsequent Form Required: ~(~,/' Q ~, A roved b : APPROVED BY COMMISSIONER THE COMMISSION Date: 6~-~i Q~ pp y Form 10-403 Revised 06/2006 - ~: ~+ ~ ~ ~ ~~~ ~ ~, Submit in Duplicate 2008 Capillary String Installation FC 4 Capillary String Install WBS: Requested Obiective Install capillary string (3/8" 2205 0.049" WT) into well for delivering foamer to alleviate liquid loading. Procedure Capstring Set Depth: TVD at Set Depth: Coil length: Tag: 6,670' 4,920' 8,250' Cuing 11-8Y coil) 6,923' (7/08) Installation Procedure: .Disconnect power to wellhouse (call electrician) MI crane, manlift. Remove wellhouse. On site: 8,000' spool, Well Head Adapter -Long (WHA), Sundry, Work Permit, Well Control Standards Sheet. Install Capillary Strin (g_ JSA): 1. MIRU BJ Dyna-Coil unit. Place liner around wellhead and truck. 2. Shut swab valve, pull tree-cap flange, remove OTIS blanking plug. ~ 3. Replace plug with WHA (note o-ring). MU flange. Pressure test 1.5x SIWHP. 4. P/LT Dyna-Coil injector with crane, run 3/8" string through injector. 5. Set Fluid Control Valve pressure = j (Setting TVD 4,920'x0.433 psi/ft H20)(1.036 foamer SG) = 2200 psi (use BHP as a safety factor). 6. MU BHA; run the 3/8" string through pack-off; attach BHA. 7. Perform "pull test" on BHA. 8. Thread pack-off assembly into 2-7/8" female connection (a wrench or chain tongs may be needed to hold the adapter from turning). Wrap wellhead with absorbents to catch drips. 9. Configure tubing to pump foamer downhole while running in, or cap tubing end. 10. Set Rattiguns to running tightness, and pump up pressure on pack-off. 11. Open swab valve. 12. Adjust Rattiguns and pressure on pack-off as needed to minimize leaks. 13. RIH to setting depth of 6,670'. 14. Set slips. Set Rattiguns; leave 1.5 times SIWHP on hydraulic pack-off. 15. Pull tubing excess through injector. 16. Cap tubing with a Swagelok cap and valve, pressure gauge, and filter. 17. Lockout Swab, Upper Master, and Lower Master as per Capstring Lockout Procedure. 18. Hookup injection line to CICM. NOTE: Start foamer at 1 gpd. 19. RDMO. Cleanup site. Sign-out. 20. Replace well house NOTE: When replacing well house, be careful of the tubing "bend" as it goes back inside if it extends through the roof. 203-221 50-133-20533-00-00 ADL - 590 262' (17' AGL) 1 /20/2004 2/4/2004 Tree cnx = 4-314" Otis Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1 N, R12W, S.M. Top of Cement (est.) ~ @ 4,588' MD (300' above 9-518" shoe) Excape System Details: - BHP monitoring line volume tank located from 5,435' - 5,471' 3-1/2" CIBP @ 6,974' 37' of cement on top of CIBP (7/23/08) - Ceramic flapper valves below each module as follows: Module 9 - 5,543' Module 8 - 5,596' Module 7 - 5,857' Module 6 - 5,947' Module 5 - 6,054' Module 4 - 6,462' Module 3 - 6,689' Module 2 - 7,327' Module 1 - NA :~ ;~ "4` ~' ~!~ p~~ ~~ v+ ~- ~.. _:~ ~, .J t ",. TD PBTD 7,910' MD 6,937' MD 6,047' ND 5,165' ND M MARATNOM Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 101' ND 0' 101' 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,840' ND 0' 1,550' 16" hole Cmt wl 434 sks of 12.5 ppg, Class G Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 4,888' TVD 0' 3,302' 12-114" hole Cmt w/ 400 sks of 12.5 ppg, Class G, Lead & 175 sks of 13.5 ppg, Class G, Tail Production Casino 3-112" L-80 9.3 ppf EUE Top Bottom Srd MD 0' 7,866' ND 0' 6,008' 8-112" hole Cmt wl 850 sks of 13.5 ppg, Class G Footage ND Patched (8R/2008) 5204-5208' 4 ft 3590-3594' 2-318", 4 SPF (1111112005) Patched 8/112008) 6' 16 ft 3732-3746' 2-318", 4 SPF (1 111 012 0 0 5) 6' 33 ft 3753-3783' 2-318", 4 SPF (1 111 012 0 0 5) 8' 13 ft 3827-3839' 2-318", 4 SPF (111912005) - 9 Excape modules placed - Red contol line fires top 8 modules - Grp-~,~ control line fires bottom 1 module - Ceramic flapper valves below each module except for Module 1 Module 9 - 5,516' - 5,526' Module 8 - 5,570' - 5,580' Module 7 - 5,832' - 5,842' Module 6 - 5,922' - 5,932' Module 5 - 6,028' - 6,038' Module 4 - 6,436' - 6,446' Module 3 - 6,664' - 6,674' '~ Cement Plug @ 6,937' 3-1/2" CIBP @ 6,974' Module 2 - 7,300' - 7,310' Module 1 - 7,644' - 7,654' Bottom of Perfs MD TVD 5,526' 3,882.1' 5,580' 3,931.0' 5,842' 4,168.7' 5,932' 4,250.6' 6,038' 4,347.1' 6,446' 4,717.9' 6,674' 4,925.1' 7,310' 5,503.7' 7,654' 5,816.1' Well Name: Falls Creek #4 Lease: Ninilchik Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,204' - 7,654' (ND): 3,592' - 5,816' Angle @ KOP and Depth: 2° 1100ft @ 200' MD Angle @ Perfs: 25° Dated Completed: 3/26/2004 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 512 1 12 0 0 9 Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON Oil Company Telephone 907/283-1371 Fax 907/283-1350 February 10, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Ninilchik Unit ~~ ~ - ~~, Well: Falls Creek #4 Dear Mr. Maunder: The AOGCC approved Marathon's requested to install a velocity string in FC-4 well on June 28, 2007, under sundry approval #307-209. The velocity string installation work has not progressed in the time frame as intended. Marathon is closing out this sundry as anon-work activity in an effort to maintain current approval dates on open sundries. A 10-403 Application for Sundry Approvals will be filled when and if Marathon determines that it is advantageous to readdress this well work option. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, - -~il'~~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Report ~E~ ~ zoa~ cc: Houston Well File Kenai Well File KJS - STATE OF ALASKA ALA OIL AND GAS CONSERVATI COM~I REPORT OF SUNDRY WELL O~R~A~I~~S rsti~rt r n~rness~ore J~G~~ a-ice-o9 ~~,21~. 1. Operations Abandon Repair Well Plug Perforation I i to Other ~ Non-Work Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ~ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon OII Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ - Exploratory^ 203-221 ' 3. Address: p0 Box 1949 Stratigraphic ^ Service^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20533-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 262' (17' AGL Falls Creek #4 8. Property Designation: 10. Field/Pool(s): ADL-590 ~ Ninilchik Unit /Beluga Formation 11. Present Well Condition Summary: Total Depth measured 7,910' - feet Plugs (measured) 6,937' true vertical g,p47' . feet .Junk (measured) NA Effective Depth measured 6,930' feet true vertical 5,159' feet Casing Length Size MD TVD Burst Collapse Structural Conductor g4' 20" 101' 101' 2,410 psi 770 psi Surface 1,823' 13-3/8" 1,840' 1,550' 3,450 psi 1,950 psi Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330 psi 3,810 psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 5,084' - 7,654' True Vertical depth: 3,472' - 5,816' Tubing: (size, grade, and MD) 3-1/2" L-80 7,866' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Marathon intended to install a velocity string in FC-4. Permission for this operation was granted in 2007. Completion of this work has not progressed while performing additional evaluation of potential Treatment descriptions including volumes used and final pressure: options. This sundry is being closed out as a non-work operation in an effort to to maintain current approval dates on open sundries. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations NA 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: 307-209 Contact Kevin Skiba (907) 283-1371 ~ ~~~ 1 %JD Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ ,- Phone (907) 283-1371 Date February 10, 2009 ~, ,+ (~~, • M Marathon MARATHON Oil Company September 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Ninilchik Unit Well: Falls Creek #4 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RG`e~ Alaska Oil $~ Gs x l~~gr~~. ~~~~r'~~iwsiArs Ancl <cra~e ,~ ~,a a - 2-~-~ Attached for your records is the Report of Sundry Well Operations 10-404 for work performed on FC-4 well. This sundry covers the placement of a cast iron bridge plug at 6,974' and the installation of two casing patches across Beluga perforation zones. This work was completed under sundry#308-251. Efforts to reduce water production were successful decreasing total fluid production by 85%. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, y • Kevin J. Skiba Engineering Technician ~~.I~E~ SAP ~ ~ 2D0~ Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS KDW y,~~ STATE OF ALASKA C/~ ALA~OIL AND GAS CONSERVATION COMMON SEA ~~'~LOO~ REPORT OF SUNDRY WELL OPERA~ION~S 1. Operations Abandon Repair Well Plug Perforations ~ ~ Stimulate Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ i Exploratory^ 203-221 , 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20533-00-00 7. KB Elevation (ft): 9. Well Name and Number: 262' (17' AGL) Falls Creek #4 ' 8. Property Designation: 10. Field/Pool(s): ADL-590 Ninilchik Unit /Beluga Formation 11. Present Well Condition Summary: Total Depth measured 7,910'' feet Plugs (measured) 6,937" true vertical 6,047' . feet Junk (measured) NA Effective Depth measured 6,930' feet true vertical 5,159' feet Casing Length Size MD TVD Burst Collapse Structural Conductor g4' 20" 101' 101' 2,410 psi 770 psi Surface 1,823' 13-3/8" 1,840' 1,550' 3,450 psi 1,950 psi Intermediate 4,871' 9-5/8" 4,888' 3,302' 6,330 psi 3,810 psi Production 7,849' 3-1/2" 7,866' 6,008' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 5,084' - 7,654" True Vertical depth: 3,472' - 5,816' Tubing: (size, grade, and MD) 3-1/2" L-80 7,866' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Placed cast iron bridge plug at 6,974' and dump bailed 37' of cement on top. Installed two casing patches at (5,081'-5,098') and (5,312'- Treatmentdescriptions including volumes used and final pressure: 5,333'). 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,755 266 0 317 Subsequent to operation: 0 1,515 39 0 312 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 0~ 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: 308-251 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Production Engineer Signature ~ ~,J~~ ~ Phone (907) 283-1311 Date September 4, 2008 Form 10-404 Revised 04/2006 ~"~'~ .. ~ Submit Original Only ~ _ ,,~ ~1t7 ~~~ ', Marathon ' Operations Summary Report ' +~~' ~,OiiCOmpany Well Name: FALLS CREEK 4 Daily Operations Report Date: 7t2412008 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Expro to run 2.60" GR and set 3-112" CIBP @6974' KB. Start Tlrne Sr d T~rr~t Cvr (hrs) Ops Cotle Activity Code Ops Status Trouble Code Comment :00 10:30 ~ 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Expro JSA and sepecific job hazards, as well as assign job responsibilities. Obtain SWP. : 0 11:45 1.25 RURD ELEC AF Spot equipmentto well house. RU Eline unit. PU lubricator. MU tool string RS, 12' stem, CCL, hydraulic jars, spanges, and 2.60" GR. Carry lubricator to WH :45 24 12:24 0.65 TEST E~IP AF . PTest lubricator to 1000 psi. Test good. 1400 1.60 RUNPUL ELEC AF RIH{1) w12.60" GR. Set down in modules 6 & 7. Work down thru. Set down @ 6900' KB. POOH. 0 14:12 ! 0.20 SAFETY MTG AF Hold explosives safety meeting. Shut down all radioes and cell phones. Post signage and guard at pad entrance. :12 1 :51 1.65 RUNPUL ELEC AF RIH 2 wi 3-112" CIBP. Tag "new" TD @ 6991 Set CIBP @ 6974' KB POOH 1 16:51 1.00 RUNPUL ELEC AF . . RIH{3) w! 2.812" GR. Run into 5450' KB. POOH .51 17:33 0.70 RURD ELEC AF . RD Eline unit. 3 17:48 I 0.25 SECURE WELL AF Secure well and location. Turn in SWP. Sign out and leave loc. Report Date: 8/112008 Job Cate ory: R&M MAINTENANCE 24 Hr Surnn~sry MIRU Expro to dump bail cement on top of CIBP set @ 6974' KB. Start Time Er~arime Dur (hrs OpsCode ActiviryCode Ops Status Trouble Cotle Comment .00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Expro JSA and specific job hazards. Make job assignments. Obtain SWP. . 0 09:30 1.00 RURD ELEC AF Spot equipment. Lay out drip liners. RU E line unit. PU lubricator and BOP's. _ MU tool string wl CCL and 40 x 2" dump bailer. 0 09:45 ~ 0.25 SAFETY MTG AF Hold explosives safety meeti ng. Check stray voltage and attach grounding straps. Shut down all cell phones and radios. Post signs and station guard at the pad entrance. 45 10:57 I _ 1.20 RURD ELEC AF Arm bailer. Mix cement. Fill bailerwl5 aallons of slurry 7 12:03 1.10 RUNPUL ELEC AF ;, RIH{1) w. 2" bailer. 11:00 am Call MR. Jim Regg give 24 hour notice to witness I tag on cement. Tag CIBP @ 6967' KB. PUH to 6960' KB {CCL depth 6918') ' Shoot bailer. Eject cement. POOH. 3 12:33 0.50 RURD ELEC AF OOH. Bailer MT. Shut down radios and cell phones. Station guard at the gate. Re-arm bailer. Mix cement. Fill bailer w15 gallons of slurry. 3 13:33 1.00 RUNPUL ELEC AF RIH{2) w. 2" bailer. Run correlation log to get on depth. RIH to 6957 KB {CCL depth 6915'). Shoot bailer. Eject cement. POOH. 3 13:57 ! 0.40 RURD ELEC AF OOH. Bailer MT. Shut down radios and cell phones. Station guard at the gate. Re-arm bailer. Mix cement. Fill bailer w! 5 gallons of slurry. 7 15:03 " 10 RUNPUL ELEC AF RIH{3} w 2" bailer. Run correlation log to get on depth. RIH to 6946' KB {CCL depth 6904'}. Shoot bailer. Eject cement. POOH. 15:45 i`i ?0 RURD ELEC AF RD E line unit for the night. LD 40' x 2" bailer. LD lubricator and BOP's. Drop 3 soap sticks. Install tree cap and Ptest. Close swab valve. .4 16:00 0.25 SECURE WELL AF Secure well and location for the night. Turn in permit and sign out. Leave loc. Report Date: 8I't12008 Job Category: R&M MAINTENANCE 24 Hr Surnrnary MIRU Expro to tag top of cement on CIBP set @ 6974' KB Top of cement @ 6930' KB Set first patch across perforation interval 5316' - 5329' KB {13') Patch ' ' ' . 5312 - 5333 {21.5 long}. StartTirne Er~aTirr,e Dur (hrs OpsCotle Activ Code Ops Status Trouble Cotle Comment 08:00 08.30 i 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss ___ Expro JSA and specific job hazards. Make job assignments. Obtain SWP. 08:30 09:15 ~ 0.75 RURD ELEC AF PU lubricator. and BOP's. MU tool string-2.45" GR, sj, oj, weight bar{9.5' _ closed 12' open), CCL. Carry lubricator to WH. 09:15 09:39 0.40 --- TEST E~IP AF PTest lubricator to 1500 psi. Test good. 09:39 11:24 ; ; 5 RUNPUL ELEC AF RIH {1 } w12.45" GR. Correlate to get on depth. Ta cement top @ 6930' KB 37' of cement on CIBP .PUH logging thru patch interval. Flag line or epth reference at top module. POOH. www.peloton.com Report Printed: 9!312008 M Marathon wr Operations Summary Report ~ ^awaTMa~ ~OilCompany Well Name: FALLS CREEK 4 Start Time End Time Gur (hrs) Ops Cade Activity Cotle Ops Status Trouble Code Comment 11:24 14:48 I 3.40 WAITON EOIP AF Rods for setting patch had bad threads. Drive to Nikiski for replacements. Wait on equipment. 14:48 15:00 0.20 RURD ELEC AF Assemble 20' x 2.75" patch w! 2.81" O.D. elements. 1 :00 15 12 0.20 SAFETY MTG AF Hold pre-arming Explosives SM. Shut down all radios and cell phones. Check for stray voltage and grounds. Post signs and station guard at pad entrance. 1 :12 15:36 ~ 0.40 RURD ELEC AF Arm setting tool. MU setting tool and patch. Pull patch into lubricator. PU lubricator and carry to WH. :36 17:21 1.75 RUNPUL ELEC AF RIH{2) w! 20' patch to set across pertorations from 5316' - 5329'KB (13'}. Run correlation log thru patch interval. No shortjoint available for reference. Marked Eline on previous run. Mark compares well to correlation. Pull CCL up to 5301.5' (10.5' to top element of patch. Set Datch from 5312'- 5333' fCH){ ' Patch 21.5' center of element to center of element). Set down on patch. patch takes weight. POOH. - 1 17:51 0.50 RURD ELEC AF RD E line unit. LD lubricator and BOP's. LD tool string. Install and PTesttree ~' _ cap. Drop 3 soap sticks. Turn well over to production, 1 18:06 0.25 SECURE WELL AF Secure well and location. Turn in permit. Sign out and leave loc. Daily Operations Report Date: 8/812008 Job Cate ory: R&M MAINTENANCE 24 Hr Summary MIRU Expro to set second 15' Owen patch across perforation interval 5084' - 5094' KB {10'). Patch 5081' - 5098' (16.5' long}. Start Time Entl Time Dur hrs Ops Cotle Activi Code Ops Status Trouble Cotle Comment 00 08:45 I 0.75 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Expro JSA and specific job hazards. Make job assignments. Obtain SWP. 5 10:03 1.30 RURD ELEC AF Spot equipment. RU E-line unit. PU lubricator and BOP's. MU tool string- rs, CCL, Baker setting tool, 16.5' Owen Patch. 10:15 ~, 0.20 SAFETY MTG AF Hold Explosives SM. Check stray voltage and grounds. Shut down all cell ~ phones, radios, and Scada. Post signage and station guard at pad entrance. 10:27 _ ~ 20 RURD ELEC AF Arm setting tool. Carry lubricator to WH. 7 10:57 i C 50 TEST EOIP AF PTest lubricator to 1500 psi. Test good. 7 12:15 I 1 30 RUNPUL ELEC AF RIH (1} w12.68" Owen Multistage setting tool and 16.5' patch. Tag first patch @ 5312' KB. PUH logging correlation pass. Pull up into position CCL depth 5070.5' { CCL to top patch element 10.5'}. Set p across Derfs cni 5084-5094. Patch de th 5081' - 5098'. 4 minutes to fire patchsetting tool. ost some weig t. an set weight back down on patch. POOH. Bring well ~ back on production. 13:39 i'~ r1UNPUL ELEC AF RIH {2} w! 1.90 "tapered swage and fluted centralizer for adrift/ correlation run _ _ thru the patches. Looks good to 5600'. POOH. 14: 0.80 RURD ELEC AF RD E line unit. LD lubricator and BOP's. LD tool string. Drop 3 soap sticks. Install tree cap and PTest. Test good. 14:42 0.25 SECURE WELL AF Secure WH and location. Turn in permit. Sign out and leave loc. 2 14:42 Report Date: 8I16f2008 Job Cate ory: R&M MAINTENANCE 24 Hr Summary MIRU Expro to tag TD@ 6923' KB and run PT Survey. Start',rna Entl Time Dur (hrs 0 s Cotle Activi Code Ops Status Trouble Cotle Comment 08:00 08:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss _ Expro JSA and specific job hazards. Make job assignments. Obtain SWP, 08:30 9:36 1.10 RURD ELEC AF Spot equipment. RU E-line unit. PU lubricator and BOP's. MU tool string- rs, 2 ea. 1-11!16" wt bars, gamma ray, CCL, PT guages. Carry lubricator to WH. 09:36 09:48 ~ 0.20 TEST EQIP AF PTest lubricator. Test good. 09:48 12:33 2.75 RUNPUL ELEC AF RIH (1) w/ PT gauges, 323 psi., 50 degree F. Tag fluid level @ 6670' wlm. Tag fill @ 6923' KB (Top of cement on CIBP is 6930'} 798 psi, 100 degrees F. POOH. 1233 13:21 0.80 RURD ELEC AF OOH- 329 psi., 49 degrees F. RD E line unit. LD lubricator and BOP's. LD ' tool string. Install tree cap and PTest. Test good. 13:21 13:36 0.25 SECURE WELL AF Secure WH and location. Turn in permit. Sign out and leave loc. 13.36 _ _ 1 :36 www.peloton.com Report Printed: 9f312008 API: 50-133-20533 RT-GL: 16.50' RT-TH F: 16.20' Tree cnx = 4-3/4" Otis Falls Creek #4 Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1 N, R12W, S.M. Top of Cement (est.) @ 300' above 9-5/8" shoe' BHT: Footage ND Patched (8/712008) 5204-5208' 4 ft 3590-3594' 2-3/8", 4 SPF (11/1112005) Patched 8/112008) 5360-5376' 16 ft 3732-3746' 2-3/8", 4 SPF (11/10/2005) 5383-5416' 33 ft 3753-3783' 2-3/8", 4 SPF (11/1012005) 5465-5478' 13 ft 3827-3839' 2-3/8", 4 SPF (11/9/2005) 3-1/2" CIBP @6974' (7/23/08) 37' of cement on top of CIBP :cape System Details: Ceramic flapper valves below each module as follows: Module 9 - 5543' Module 8 - 5596' Module 7 - 5857' Module 6 - 5947' Module 5 - 6054' Module 4 - 6462' Module 3 - 6689' Module 2 - 7327' Module 1 - NA Well Name & Number: County or Parish: Perforations (MD) Angle/Perfs BHP: Dated Completed: Revised By: • M MARATHON Drive Pipe: 20", 133 ppf, K-55 to 101' . ~ Surface Casing: 13-3/8", 68 ppf, K-55, BTC @ 1840' Cmt w/ 434 sks of class G at 12.5 ppg Int. Casino: 9-5/8", 47 ppf, L-80, BTC @ 4888' Cmt w/ 400 sks of class G lead at 12.5 ppg & 175 sx of class G tail at 13.5 ppg -, Prod. Tubing: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 7866' Cmt w/ 850 sks of class G at 13.5 ppg ~. ~. w ^ TD - 7,910' PBTD - 6,937' FC #4 Lease: Kenai State/Prov. KOP and - 9 Excape modules placed - Red contol line fires top 8 modules -Green control line fires bottom 1 module - Ceramic flapper valves below each module except for Module 1 Module 9 - 5516'-5526' Module 8 - 5570'-5580' Module 7 - 5832'-5842' Module 6 - 5922'-5932' Module 5 - 6028'-6038' Module 4 - 6436'-6446' Module 3 - 6664'-6674' Cement Plug @ 6,937' 3-1/2" CIBP @ 6974' Module 2 - 7300'-7310' Module 1 - 7644'-7654' Ninilchik Gas Field Alaska Country: USA (TVD) Fluid: 6% KCL Mike Sulley I Last Revison Date: 5526 3882.063 5580 3930.947 5842 4168.742 5932 4250.568 6038 4347.079 6446 4717.919 6674 4925.108 7310 5503.747 7654 5816.146 • ~~Q~ ~ C~~ G~ ~;,aS~n(G~ ALASB-A OIL A1~TD GAS C01~TSER~ATIO~' COIrII->[ISSIOI~T Ken Walsh Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~AJ1~F.~ JUG. I °~ 2D08 ~~13-~~I Re: Ninilchik Gas Field, Tyonek Undefined Gas Fool, Falls Creek #4 Sundry Number: 308-251 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. When providing 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 bf 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, Jr. DATED this l~o day of July, 2008 • Encl. Sin~PrPly_ r: M Marathon MARATHON Oil Company July 11, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Application for Sundry Approvals 10-403 Field: Ninilchik Unit Well: Falls Creek #4 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~ ~,~ <,. t.,c~t~,~~~icn f,r: , -~ Submitted for your approval is the 10-403 Application for Sundry Approvals for FC-4 well. FC-4 is presently producing about 250 barrels of water per day. Marathon proposes to isolate the main volume of this infiltrating water by placing patches across the top two production intervals along with installing a plug above the lower two production intervals. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice Proposed Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS KDW ~~~%~ ~ STATE OF ALASKA ~JU( ~ ~ ~~~~ ,,~ AL~ OIL AND GAS CONSERVATION COM~SION -~'~ APPLICATION FOR SUNDRY APPROVA~~`~ ~~`~ ' ~~~ `~ ~ . , r, ~n aac ~~ ~An 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations Q ~ Stimulate ^ Time Extension ^ Ghange approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Develo ment p ^ , Exploratory ^ 203-221- 3 A . ddress: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20533-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ Spacing Exception Required? Yes ^ No ~ Falls Creek #4 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL-590 262' (1T AGL)~ Ninilchik Gas Field 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective bepth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7910' 604T ~ 7829' ' 5974'' NIA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 101' 101' 2410 psi 770 psi Surface 1823' 13-3/8" 1840' 1550' 3450 psi 1950 psi Intermediate 4871' 9-5/8" 4888' 3302' 6330 psi 3810 psi Production 784g' 3-1/2" 7866' 6008' 10160 psi 10540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5084'- 7654' 3472'- 5816' 3-1 /2" L-80 7866' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development 0 Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: 7/21/2008 9 P ^ Oil ^ Gas Q Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer Signature /'„ , _ ~ ~ Phone (907) 283-1311 Date 7/11/2008 IJ~ ' ~(,J , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (~~ a 5l .Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ,w ~ ~-`1 v~ ,7V ~ ~ a ~ ~',r~~ i v~ G.~C-C..fl ~ ~l d ©~ Q-~ ~. Subsequent Form Required: ~®'~ APPROVED BY Approved by: ~ O ISSIONER THE COMMISSION Date: ~~6 ~ ~ Form 10-403 Revised 06/2l~ I \ ~ ~ I ~~ L ~~ ~~~ 2 ~ 2~Q8 Submit in Duplicate • • MARATHON OIL COMPANY ALASKA REGION MARATHON Ninilchik Field Falls Creek #4 Set Plug and Owen Casing Patches WBS # W0.0818344.EXP 7/11/2008 History: FC-4 is making about 250 BWPD. The well had perforations added and was put on compression at about the same time so the source of the water is not clear from the history. It appears that around 40% of the water came before the add perfs and 60% after. The log analysis indicates that we may be producing some water from bottom and are producing water from the top 2 intervals. The latest fill tag depth was 7144' MD on 2/22/2008. Objective: Set a plug above the bottom 2 intervals and set patches across the top 2 intervals to shut off water. 1) MIIZU Pollard Wireline to run dummy casing patch. a. Hold PJSM. b. MU pump-in tee and Wireline valve to Otis tree cap connection. PU lubricator and pull centralized 3.75" OD GR, spang jars, oil jars, stem, and weight bars into lubricator. Shut well in. c. Take lubricator to wellhead. Pressure test lubricator with 6% KCL water to 250/2800 psi. d. RIH with GR to 7,300' KB. POOH. Must be below 6,680'. e. RIH with 3.80" OD swage, spang jars, oil jars, stem, and weight bars on slickline to 7,300' KB. POOH. f. RIH with 3.80" OD wire brush, spang jars, oil jars, stem, and weight bars on slickline to below 6,700' MD. POOH. g. RIH with bottom 3.80" dummy patch element, 10' section of 3.75" OD patch sleeve, and top 3.80" OD dummy patch element, crossover, 8' 2-3/8" tubing pup, crossover, bait sub, spang jars, oil jars, and stem on slickline to 5,350' KB. POOH. h. RIH with bottom 3.80" dummy patch element, 13' section of 3.75" OD patch sleeve, and top 3.80" OD dummy patch element, crossover, 8' 2-3/8" tubing pup, crossover, bait sub, spang jars, oil jars, and stem on slickline to 5,350' KB. POOH. i. RDMO Pollard Wireline. 2) MIRU Expro Wireline Unit to set Plug. a. Hold PJSM and complete Work Permit form. Record the last 24-hour average FTP and water and gas flowrates on We1lView. Imuortant Note: Arrange with NGF Operators to maintain this specific FTP throughout the rest of the flow tests in Steps #2 through #5 to allow proper evaluation of the impacts to production following each patch that is set. This FTP is expected to be around 1350 psi. b. NU Wireline valve with pump-in sub to 3-1/16" lOK tree. a MU and PU sufficient 3-1/2" lubricator to seta 3-1/2" CIBP. Go to Radio Silence while arming setting tool. d. MU and pull into lubricator with 3-1/2" CIBP (2.50" running OD, lOK differential), setting tool, and CCL. Page 1 of 3 7/11/2008 Falls Creek #4 Plug/Casing Patch • • e. Take lubricator to wellhead. Pressure test lubricator to 250/2800 psi with KCL water. RIH to desired correlation depth below perforation interval, 6,664'-6,674' KB. Set CIBP between 7144' (latest fill tag depth) and 6750' MD but as deep as possible within that range. POOH and LD setting tool. £ PU and RIH with cement dump bailer. Bail at least 50' of cement on top of CIBP. LD lubricator. g. RDMO Expro. h. Flow test well through test separator with particular emphasis on measuring the daily produced water and gas volumes at the same FTP as noted above. 3) MIRU Expro Wireline Unit to set First casing patch across 5,316'-5,329' KB. a. Hold PJSM and complete Work Permit form. b. NU Wireline valve with pump-in sub to 3-1/16" lOK tree. c. MU and PU sufficient 3-1/2" lubricator to seta 24' long casing patch. d. MU and pull into lubricator 2' Owen PAT-3500-002, 9.2-9.3 ppf short assembly, 20' Casing Patch, setting tool, 2' Owen PAT-3500-002, 9.2-9.3 ppf short assembly , 2-1/8" OD Multi- Stage setting tool, and CCL. Go to Radio Silence and arm setting tool. e. Take lubricator to wellhead. Pressure test lubricator to 250/2800 psi with methanol water. RIH to desired space out for depth correlation below perforation interval, 5,316'-5,329' KB. Set casing patch with top of short assembly at 5,311' KB (top of patch at 5,313' KB). POOH and LD setting tool. LD lubricator. f. RDMO Expro. g. Flow test well through test separator with particular emphasis on measuring the daily produced water and gas volumes at a stabilized FTP. 4) MIRU Expro Wireline Unit to set Second casing patch across 5,084'-5,094' KB. a. Hold PJSM and complete Work Permit form. b. NLT Wireline valve with pump-in sub to 3-1/16" lOK tree. c. MU and PU sufficient 3-1/2" lubricator to seta 19' long casing patch. d. MU and pull into lubricator 2' Owen PAT-3500-002, 9.2-9.3 ppf short assembly, 15' Casing Patch, setting tool, 2' Owen PAT-3500-002, 9.2-9.3 ppf short assembly , 2-1/8" OD Multi- stage stting tool, and CCL. Go to Radio Silence and arm setting tool. e. Take lubricator to wellhead. Pressure test lubricator to 250/2800 psi with water. RIH to tag top of previous casing patch at 5,311' KB. Set correlation patch with top of short assembly at 5,080' KB (top of patch at 5,082' KB) and across perforation interval, 5,084'-5,094' KB. POOH and LD setting tool. LD lubricator. f. RDMO Expro. g. Flow test well through test separator with particular emphasis on measuring the daily produced water and gas volumes at a stabilized FTP. 5) Flow well to production facility. Patch Dimensional and Pressure Data: Burst = 6,180 psi Collapse = 6,510 psi. Top and bottom swage running OD = 2.812" Sleeve OD = 2.75" Patch ID after setting = 2.375" Page 2 of 3 7/11/2008 Falls Creek #4 Plug/Casing Patch • CONTACTS Ken Walsh Lyndon Ibele: 907-283-1311 (w) 907-394-3060 (c) 907-565-3042 (w) 907-748-2819 (c) C~ Scott Szalkowski: Clyde Scott: 713-296-3390 (w) 713- 301-9834 (c) 713-296-2336 (w) Ninilchik Operators: 907-260-7660 or 907-567-3248 (Susan Dionne Pad) KGF Operators: 907-283-1305 Page 3 of 3 7/11/2008 Falls Creek #4 Plug/Casing Patch API: 50-133-20533 RT-GL: 16.50' RT-THF: 16.20' Tree cnx = 4-3/4" Otis Fal~Creek #4 Ninilchik Unit 1842' FSL, 2842' FWL, Sec. 6, T1 N, R12W, S.M. Proposed TOC (est.) - 300' above 9-5/8" shoe' Excaoe System Details - BHP monitoring line volume tank located from 5435' - 5471' Ceramic flapper valves below ach module as follows: M M~~rnoN Drive Pioe: 20", 133 ppf, K-55 to 101' Surface Casing: 13-3/8", 68 ppf, K-55, BTC @ 1840' Cmt w/ 434 sks of class G at 12.5 ppg Int. Casing: 9-5/8", 47 ppf, L-80, BTC @ 4888' Cmt w/ 400 sks of class G lead at 12.5 ppg & 175 sx of class G tail at 13.5 ppg Prod. Tubing: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 7866' Cmt w/ 850 sks of class G at 13.5 ppg Patched (71 TBD /2008) 5204-5208' 4 ft 3590-3594' 2-3/8", 4 SPF (11/11/2005) Patched (7/TBD /2008) 2-3/8", 4 SPF (11/10/2005) 2-3/8", 4 SPF (11/10/2005) 2-3/8", 4 SPF (11/9/2005) 3-1/2" CIBP Between 6~°" - . , Tagged fill 2/22/08 @ 7144'MD 9 Excape modules placed Green control line fires bottom 1 module Red contol line fires top 8 modules Ceramic flapper valves below each iodule except for Module 1 e 9 - 5516'-5526' e 8 - 5570'-5580' e 7 - 5832'-5842' e 6 - 5922'-5932' e 5 - 6028'-6038' e 4 - 6436'-6446' 3 - 6664'-6674' CIBP within 6750' 7144 2 - 7300'-7310' 1 - 7644'-7654' TD - 7910' PBTD - 7829' • • rte,., ~"~`°~•; MICROFILMED 03/01/2008 DO NOT PLACE ~`.. ,~.. ~9- ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts~Microfilm_Marker. doc . ~],~],Œ (ID~ ~~~~[K\~ . AI,.SIiA. OIL A5D GAS CONSERVATION COltDllSSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 Re: Ninilchik Gas Field, BelugajTyonek Gas Pool, Falls Creek #4 Sundry Number: 307-209 SCANNED JUt 0 [) 2007 Dear Mr. Donovan: 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. When providing 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 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. DATED this z! day of June, 2007 Enc!. 863-6>&1 . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 Marathon Oil Company June 13, 2007 RECEIVED JUN 2 5 2007 Alaska Oi/ & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Ninilchik Gas Field Well: Falls Creek # 4 Dear Mr. Maunder: We propose to run a 1.75" velocity string in FC #4. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. sincereIY.~~. Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic Operation Summary cc: AOGCC Houston Well File Kenai Well File DMD KJS 20M 25. . . 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate D Waiver IT'" Other [] Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D V-String Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil ComDanv Development [] Exploratory D 203-221 - 3. Address: Stratigraphic D Service D 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20533-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes l./. No [] Falls Creek # 4 - 9. Property Designation: ~.I)L t7000sø ~ 10. KB Elevation (ft): 11. Field/Pool(s): 1842' FSL. 2842' FWL, Sec.6, T1N, R12W, S.M. 16.5' Ninilchik Gas Field - 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7910' ~ 6047' 7829' - 5974' - N/A N/A , Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101' 2410 psi 770 psi Surface 1840' 13-3/8" 1840' 1550' 3450 psi 1950 psi Intermediate 4888' 9-5/8" 4888' 3302' 6330 psi 3810 psi Production 7866' 3-1/2" 7866' 6008' 10160 psi 10540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5084'-7654' 3472'-5816' 3-1/2" L-80 7866' Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 13. Attachments: Description Summary of Proposal D 14. Well Class after proposed work: Detailed Operations Program [] BOP Sketch D Exploratory D Development [] Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 28-Aug-07 Oil D Gas [] Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name k I Dennis Donovan Title Production Engineer Signature Phone (907) 283-1333 Date 13-Jun-07 ~WJ-~n . ~ - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~01'" :JOC?J Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~g:c <.."\ ~O ~ .~ ~ \- G..s. ~\o.,,~~ Subsequent Form Required: Y{Jt; m f/J/ APPROVED BY ~ THE COMMISSION Date: b- p8,() l' Approved by: v ,. MMISSIONER Form 10-403 Revised 06/2006 o R1 5lNAr / ø$~ in Duplicate ~. Rt::l;I::IVI::U CA'1-1t".1 STATE OF ALASKA ~~-. ALAS'ð'OIL AND GAS CONSERVATION COMMWoN fJ(..1~(UN 2 5 2007 APPLICATION FOR SUNDRY APPROVA~&ka Oil & Gas Cons. Commíssíon C 280 . . MARATHON OIL COMPANY ALASKA REGION Ninilchik Gas Field Falls Creek # 4 2007 CT Velocity String Hangoff Procedure Notes: . This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. . Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real-time Flowina Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil Tubina Head. 3. Make flowline modifications for coil tubina velocitv strina. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back eQuipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical ~onnections. 5. MIRU BJ coiled tubina unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHA). Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 Ibs. Nipple up injector to WHA. 7. Pressure test surface lines and CT eQuipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in well bore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. . . Page 2 of2 10. Nipple UP injector 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 seNe as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubina velocitv strina and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubina. PUH to span WHA for final landing depth. 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. 13. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 Ibs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanaer per Vetco procedures. 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). Tighten Lock Screws. 15. Release 3" GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purae N2 from CT remainina in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release eQuipment. RD flowback iron. Release tanks and all rental equipment to vendors. API: 50-133-20533 RT -GL: 16.50' RT-THF: 16.20' 1842'FSL,2842'FVVL,Sec.6, T1N, R12W, S.M. Tree cnx = 4-3/4" Otis FC#4 ITOC (est.) - 300' above 9-5/8" shoe' I Excape System Details - BHP monitoring line volume tank located from 5435' - 5471' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 5543' Module 8 - 5596' Module 7 - 5857' Moduie 6 - 5947' Module 5 - 6054' Module 4 - 6462' Module 3 - 6689' Module 2 - 7327' Module 1 - NA Well Name & Number: County or Parish: Perforations (MD) BHP: Dated Completed: Prepared By: TD - 7910' PBTD - 7829' FC#4 Kenai I Drive Pipe: 20", 133 ppf, K-55 to 101' Surface Casinq: 13-3/8",68 ppf, K-55, BTC @ 1840' Cmt w/434 sks of class G at 12.5 ppg Int. Casinq: 9-5/8", 47 ppf, L-80, BTC @ 4888' Cmt w/400 sks of class G lead at 12.5 ppg & 175 sx of class G taii at 13.5 ppg Prod. Tubinq: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" 00 control line protectors to 7866' Cmt w/850 sks of class G at 13.5 ppg Excape System Details - 9 Excape modules placed - Green control line fires bottom 1 module - Red contolline fires top 8 modules - Ceramic flapper valves below each module except for Module 1 Perfs MD (RKB): Module 9 - 5516'-5526' Module 8 - 5570'-5580' Moduie 7 - 5832'-5842' Module 6 - 5922'-5932' Module 5 - 6028'-6038' Module 4 - 6436'-6446' Module 3 - 6664'-6674' Module 2 - 7300'-7310' Module 1 - 7644'-7654' Aiaska USA (TVD) 6% KCL last Revison Date: 10/19/2005 KDVV API: 50-133-20533 PROPOSED FC#4 RT-GL: 16.50' RT-THF: 16.20' 1842'FSL, 2842'FVVL, Sec. 6, T1N, R12W, S.M. Tree cnx = 4-3/4" Otis ITOC (est.) - 300' above 9-5/8" shoe' I Excape System Details - BHP monitoring line volume tank located from 5435' - 5471' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD IRKB): Module 9 - 5543' Module 8 - 5596' Module 7 - 5857' Module 6 - 5947' Module 5 - 6054' Module 4 - 6462' Module 3 - 6689' Module 2 - 7327' Module 1 - NA TD - 7910' PBTD - 7829' Well Name 8. Number: County or Parish: Perforations (MD) FC#4 Kenai Lease: tate/Provo BHP: Dated Completed: Prepared By: Angle BHT: ¡Drive Pipe: 20",133 ppf. K-55 to 101' Surface CasinQ: 13-3/8". 68 ppf, K-55, BTC @ 1840' Cmt w/434 sks of class G at 12.5 ppg Int. CasinQ: 9-5/8", 47 ppf, L-80, BTC @ 4888' Cmt w/ 400 sks of class G lead at 12.5 ppg & 175 sx of class G tail at 13.5 ppg Prod. TubinQ: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 7866' Cmt w/ 850 sks of class G at 13.5 ppg Excape System Details - 9 Excape modules placed - Green control line fires bottom 1 module - Red contolline fires top 8 modules - Ceramic flapper valves below each module except for Module 1 Perfs MD IRKB): Module 9 - 5516'-5526' Module 8 - 5570'-5580' Module 7 - 5832'-5842' Module 6 - 5922'-5932' Module 5 - 6028'-6038' Module 4 - 6436'-6446' Module 3 - 6664'-6674' Module 2 - 7300'-7310' Module 1 - 7644'-7654' Alaska USA (TVD) 6% KCL Last Revison Date: 10/19/2005 KDW to c, . . Marathon Oil Company Øperations Summary Report of 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: FALLS CREEK 4 FALLS CREEK 4 MAINTENANCE/REPAIR NABORS DRILLING NABORS DRILLING COde50~e Phase 7/13/2006 11 :00 - 11 :30 0.50 SAFETY MTG_ SLICK 11:30 - 12:30 1.00 RURD_ SLlK SLICK 12:30 - 13:30 1.00 RUNPUL SLlK SLICK 13:30 - 16:30 3.00 LOG_ CSG_ SLICK 16:30 - 17:30 1.00 RURD_ SLlK SLICK Start: Rig Release: Rig Number: Spud Date: 1/20/2004 End: Group: 7/12/2006 129 Description of Operations Held PJSM with Expro and MOC personnel to review Safe Work Permit conditions and operational plan. MIRU Expro slickline unit to run a memory PoT log. SITP at 11 :00 hrs on 7/12/2006 was 1022 psig. Well has been shut in since 10:30 hrs on 7/11/2006. MU wireline valve and flowtee to top of swab valve tree cap. MU 2" OD gauge ring to 1-3/4" OD slickline tool string and pulled into lubricator. Took lubricator to well and pressure tested to 2000 psig. Bled back pressure and fluid. RIH with 2" GR. Tagged and worked quickly through Module #9 flapper area at 5543' KB. Tagged and worked quickly through Module #3 flapper area at 6689' KB. RIH to 7290' WLM (7306.5' KB) and could not work any deeper. Very sticky pulling off bottom tag depth. Acting like something was dragged up hole with tools for about 50'. MU 1-11/16" OD memory poT tool string (removed roller centralizer section to help pass through Excape modules) with spang and oil jars and weight bar on 1-3/4" tool string. Opened well and RIH with memory poT tool string on slickline to 4900' WLM (4916.5' KB). Logged down pass at 70 fpm to tag same depth of 7307' KB. While taking static bench, tool fell through to 7328' KB. Worked stuck tool loose after 10 minutes and pulled uphole dragging hard until tool became free at 6965' KB. Logged up pass to 4500'. POOH taking static benches at 4500' and every 500' to surface. Returned well to production. LD memory tool string, lubricator, and wireline valves. RDMO Expro slickline. Printed: 6/1912007 1:40:08 PM Mr.. Okland - Please accept my apology for not getting back with you sooner, but I have been out of town on business. Please see formation top information from our Geologist, David Brimberry, for FC #4 per your request. If you have any questions regarding this information please let me know. I am also sorry for it not being in the original completion report. Thank you. J. R. Thompson Sr Production I Completion Engineer Alaska Asset Team Marathon Oil Company - Houston, TX. W: 713-296-2730; M: 713-232-9347; Fax: 713-513-6019 Email: JRThompson@MarathonOil.com From: Brimberry, David Sent: Friday, April 28, 20062:34 PM To: Thompson, Jim Subject: RE: Falls Creek 4 MD TVD Top Beluga 3105 2113 Top Tyonek 6694 4943 From: Thompson, Jim Sent: Friday, April 28, 20068:33 AM To: Brimberry, David Subject: FW: Falls Creek 4 Who can assist here. If they can forward this info to me I can send it on to AK. Thanks. Jim Thompson Ext.: 2730 Fax: 713-513-6019 From: Howard Okland [mailto:howard_okland@admin.state.ak.us] Sent: Monday, April 24, 20064:43 PM To: Thompson, Jim Subject: Falls Creek 4 James, Do you have formation tops for the Falls Creek # 4 (API 50-133-20533-00) well? The completion report that you submitted did not have any. TNX Howard Okland Alaska Oil and Gas Conservation Commission 00:'- ~Àl ht(~ .2 Co ~ v¡I-1-CI ~ Í4 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2032210 Well Name/No. NINILCHIK UNIT, FALLS CK 4 Operator MARATHON OIL CO API No. 50-133-20533-00-00 MD 7910 TVD 6047 Completion Date 3/26/2004 Completion Status 1-GAS Current Status 1-GAS UIC N ~-- REQUIRED INFORMATION ~-,..,--- Directional sucey~ Mud Log No Samples _ No DATA INFORMATION Types Electric or Other Logs Run: SP/GR-IEL-Density/Neutron-Sonic-Single Arm Caliper Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ C Las 12496 Induction/Resistivity p- 12496 Directional Survey E C 12496 Report: Final Well R .~ C Exc 12496 Production lEg-- C 13361 Report: Final Well R L_ Log Log Run Scale Media No Interval Start Stop 1750 7945 OHI CH Open . Received Comments GR SP Density Sonic Neutron Porosity o o 7910 o Open o o Mud Log (LAS) Morning Rpts Well Rpt Surface Testing Report I (.xls) I Final Well Report(doc) - I Mudlog (LAS and pdt) _I Morning Rpts o o Open Well Cores/Samples Information: Name C Cuttings ADDITIONAL INFORMATION Well Cored? Y / €J Chips Received? , I I<J Interval Start Stop 1860 7910 Sent Sample Set Received Number Comments 4/22/2004 1133- l . Daily History Received? ~N Formation Tops C:iÆ) A {¡~\{~ JtZ \~ ~ r~ A't ~ A~~ Analysis ~ , Received? Comments: .- _.._~~._-~--- - -----..- Permit to Drill 2032210 MD 7910 TVD 6047 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Well Name/No. NINILCHIK UNIT, FALLS CK 4 Operator MARATHON OIL CO Completion Date 3/26/2004 Completion Status 1-GAS Current Status 1-GAS Date: ----."-.-.--.--.-."----- API No. 50-133-20533-00-00 UIC N . . . . Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 February 14,2006 RECEIVED FEB 1 7 2006 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 AI.ska Oil & Gas Cons. Commission Anchorage Dear Mr. Aubert: Attached and submitted for your records is the Form 10-404 to add Tyonek perforations in the Falls Creek #4 well. Also attached for your records is the current well schematic and operational history of the work performed. The well is currently an active Beluga and Tyonek formation producer. If you would like any other information, please contact me at 394-3060 or kdwalsh@marathonoil.com. Sincerely, )ÚAA-- Ì).uJ~ Ken D. Walsh Senior Production Engineer Enclosures . STATE OF ALASKA A ALA OIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 1 7 ZOOfi 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U fJ. ~rll Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time ~ )".~ _Gas Cons. GammiSI' Change Approved Program D Operat. Shutdown D Perforate [2] Re-enter Suspended WellD Anchoraøe 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development [2] Exploratory D 203-221 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 1949, Kenai, AK 99611-1949 50-133-2053300 7. KB Elevation (ft): 9. Well Name and Number: 261.5 Ninilchik Unit: Falls Creek #4 8. Property Designation: 10. Field/Pool(s): ADL 590 Ninilchik Unit/Beluga and Tyonek 11. Present Well Condition Summary: Total Depth measured 7910 feet Plugs (measured) true vertical 6047 feet Junk (measured) Effective Depth measured 7829 feet true vertical 5974 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101' 2410 psi 770 psi Surface 1840' 13-3/8" 1840' 1550' 3450 psi 1950 psi Intermediate 4888' 9-5/8" 4888' 3302' 6870 psi 4750 psi Production 7866' 3-1/2" 7866' 6008' 10160 psi 10540 psi Liner Perforation depth: Measured depth: 5084-5094',5204-5208',5316-5329', 5360-5376', 5383-5416', 5465-5478' True Vertical depth: 3472-3490', 3590-3594', 3692-3704', 3732-3746', 3753-3783', 3827-3839' Tubing: (size, grade, and measured depth) 3-1/2" L-80 7866' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: RBDMS BFL FEB 2 1 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1718 3.2 788.7 NIA Subsequent to operation: 0 2259 16.6 783.7 N/A 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development [2] Service D Daily Report of Well Operations Attached 16. Well Status after proposed work: OilD Gas [2] WAG 0 GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡SUndry Number or NIA if C.O. Exempt: -'~ 7-330 Contact Ken D. Walsh ~ 1)./.21/0b Printed Name Ken D. Walsh Title Senior Production Engineer Signature ~~~.vJ~ Phon,e ..901-:W413060 Date 2/14/2006 _ 1"'""\ I r" Form 1 0-404 Revised 04/2004 UK\\.J\\\lnL- Submit Original Only n API: 50-133-20533 RT-GL: 16.50' RT-THF: 16.20' 1842'FSL, 2842'FVVL, Sec. 6, T1N, R12VV, S.M. Tree cnx = 4-3/4" Otis ¡TOC (est.) - 300' above 9-5/8" shoe' I Excape System Details - SHP monitoring line volume tank located from 5435' - 5471' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKS): Module 9 - 5543' Module 8 - 5596' Module 7 - 5857' Module 6 - 5947' Module 5 - 6054' Module 4 - 6462' Module 3 - 6689' Module 2 " 7327' Module 1 - NA FC#4 TD - 7910' PSTD 7829' ¡Drive Pipe: 20", 133 ppf, K-55 to 101' Surface Casinq: 13-3/8",68 ppf, K-55, STC @ 1840' Cmt wI 434 sks of class G at 12.5 ppg Int. Casinq:9-5/8", 47 ppf, L-80, STC @ 4888' Cmt w/ 400 sks of class G lead at 12.5 ppg & 175 sx of class G tail at 13.5 PPQ Prod. Tubinq: 3-1/2", 9.3 ppf, L-80,EUE 8rd with 6.25" PO control line protectors to 7866' Cmt wI 850 sks of class Gat 13.5 ppg Excape System Details - 9 Excape modules placed - Green control line fires bottom 1 module - Red contolline fires top 8 modules - Ceramic flapper valves below each module except for Module 1 Perfs MD (RKS): Module 9·5516'-5526' Module 8 - 5570'-5580' Module 7 - 5832'-5842' Module 6 - 5922'-5932' Module 5 - 6028'·6038' Module 4 - 6436'-6446' Module 3 - 6664'-6674' Module 2 - 7300'-7310' Module 1 - 7644'-7654' Well Name & Number: FC#4 Lease: Ninilchik Gas Field County or Parish: Kenai I £S.tate/Þrov. Alaska ICountry: ¡USA Perforations (MD) (TV D) I A, ~ _f_~ "'"" Depth BHP: I BHT: I CQ01Pletion Fluid: 6% KCL Dated Completed: Prepared By: J. R. Thompson I Last RevisonDate: 10/19/2005 KDVV . . Marathon Oil Company Operations Summary Report legal Well Name: FAllS CREEK 4 Common Well Name: FAllS CREEK 4 Event Name: RECOMPlETION Contractor Name: NABORS DRilLING Rig Name: NABORS DRilLING Date From Code Sub Phase Code 11/10/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPPRF 08:30 - 10:30 2.00 RURD - ELEC CMPPRF 10:30 - 11 :30 1.00 RUNPU 11 :30 - 12:30 1.00 RUNPU 12:30 - 16:00 16:00 - 17:30 1.50 RUNPU 17:30 - 18:30 CMPPRF CMPPRF CMPPRF CMPPRF 1.00 WAlTON ORDR CMPPRF 18:30 - 19:00 0.50 PERF _ CSG_ CMPPRF 19:00 - 19:30 0.50 RUNPU CSG_ CMPPRF 19:30 - 20:30 1.00 RURD_ ELEC CMPPRF 11/11/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPPRF 08:30 - 09:30 1.00 RURD - ELEC CMPPRF 09:30 - 10:00 0.50 RUNPU CSG_ CMPPRF 10:00 - 10:15 0.25 PERF - CSG_ CMPFLW 10:15 - 11 :00 0.75 RUNPU ELEC CMPFLW 11 :00 - 13:00 2.00 RUNPU CMPFLW 13:00 - 13:30 0.50 PERF - CSG_ CMPFLW 13:30 - 14:00 0.50 RUNPU ELEC CMPFLW 14:00 - 15:00 1.00 RUNPU CMPFLW Spud Date: 1/20/2004 End: Group: Start: 11/9/2005 Rig Release: Rig Number: 129 Description of Opération~ Held PJSM with Expro and MOC personnel. Reviewed Safe Work Permit and job hazards. MIRU Expro Wireline to perforate new Beluga Class II intervals. Well producing 2485 Mscfd at 755 psi FTP. Spotted equipment. MU 2.75" OD gauge ring and CCL and pulled into lubricator. Took lubricator to wellhead. RIH with gauge ring and tagged up at 5536' WLM (flapper below Module 9). POOH with GR and CCL. Swabbed about 12.4 bbls produced water to surface while POOH. Expro removed ice from grease head and tubes. Spent about 1 hour troubleshooting CCL electronics. Armed 2-3/8" carrier and took lubricator to tree. RIH with 2.375" OD perforating gun loaded 13' with TAG-2375-402NTX, 9 gm. charges, 4 SPF, and PX-1firing head on CCL. Began reducing FTP to achieve proper underbalance. Had to shut the well in to get the guns to fall past 2100' due to increased produced water flow. Waited on correlation confirmation from David Brimberry. Bled pressure down to 630 psi FTP while putting the guns on depth. Correlated depth with CBL and Composite log (no correction to open hole logs). SWI and attempted to perforated 5465-5478' MD with 650 psi surface WHP. No positive indication the gun fired. Opened well back to sales at LP. POOH with guns taking appropriate measures to lay down and disarm a live perf gun. Went to radio silence at 200' from surface. LD perf gun and disarmed firing head. No shots fired. Firing head assembly checked out. Could not find a cause of failure. Will use a different firing head tomorrow. RD Expro from wellhead. Well producing 2500 Mcfd at 781 psi FTP. Held PJSM with Expro and MOC personnel. Reviewed Safe Work Permit and job hazards. Well producing 1800 Mcfd at 780 psi FTP. Expro warmed up equipment and layed out perf gun. Closed swab valve and made up WL valve and pump-in tee to tree. Added weight bar and lubricator section. Went to radio silence. Armed 2-3/8" carrier and took lubricator to tree. RIH with 2.375" OD perforating gun loaded 13' with TAG-2375-402NTX, 9 gm. charges, 4 SPF, and PX-1firing head on CCL. Correlated depth with CBL and Composite log (no correction to open hole logs). SWI and perforated 5465-5478' MD with 630 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 630 to 940 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed 3.1 bbls water to surface with gun. Armed 2-3/8" carrier and took lubricator to tree. RIH with 14' perforating gun. Spent about 1 hour to thaw grease head and another 30 min. waiting on Operator to lower FTP. Correlated depth with CBL and Composite log (no correction to openhole logs). SWI and perforated 5402-5416' MD with 630 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 630 to 935 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed 3.3 bbls water to surface with gun. Armed 2-3/8" carrier and took lubricator to tree. RIH with 19' perforating Printed: 2/14/2006 2:20:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/11/2005 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:15 17:15 - 17:30 17:30 - 18:00 11/12/2005 18:00 - 19:30 08:00 - 08:30 . Operations FALLS CREEK 4 FALLS CREEK 4 RECOMPLETION NABORS DRILLING NABORS DRILLING To Phase 1.00 0.50 CMPFLW CMPFLW CMPFLW CMPFLW 1.50 RURD_ ELEC CMPFLW 0.50 SAFETY MTG_ CMPPRF 08:30 - 09:30 1.00 RURD_ ELEC CMPPRF 09:30 - 10:00 0.50 RUNPU CSG - CMPPRF 10:00 - 10:30 0.50 PERF - CSG - CMPFLW 10:30 - 11 :30 1.00 RUNPU ELEC CMPFLW 11 :30 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 14:00 14:00 - 14:15 14:15 - 15:00 0.50 RUNPU CSG_ CMPPRF 0.50 PERF_ CMPFLW 1.00 RUNPU ELEC CMPFLW 0.50 RUNPU CSG_ CMPPRF 0.25 PERF _ CSG_ CMPFLW 0.75 RUNPU ELEC CMPFLW Spud Date: 1/20/2004 End: Group: Start: 11/9/2005 Rig Release: Rig Number: 129 Description of gun. Correlated depth with CBL and Composite log (no correction to openhole logs). SWI and perforated 5383-5402' MD with 690 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 690 to 980 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed 1.4 bbls water to surface with gun. Armed 2-3/8" carrier and took lubricator to tree. RIH with perforating gun. Correlated depth with CBL and Composite log (no correction to openhole logs). SWI and perforated 5360-5376' MD with 660 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 660 to 980 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed 3.4 bbls water to surface with gun. Swabbed a total of 11.2 bbls produced water. RD Expro from wellhead. Well producing 2840 Mcfd at 775 psi FTP. Held PJSM with Expro and MOC personnel. Reviewed Safe Work Permit and job hazards. Well producing 2400 Mcfd at 775 psi FTP. Produced/swabbed 18.2 BW yesterday. Well has produced 6.3 BW in 8 hrs (since midnight) today. Expro warmed up equipment and layed out perf gun. Closed swab valve and made up WL valve and pump-in tee to tree. Went to radio silence. Armed 2-3/8" carrier and took lubricator to tree. RIH with 2.375" OD perforating gun loaded 13' with TAG-2375-402NTX, 9 gm. charges, 4 SPF, and PX-1firing head on CCL. Correlated depth with CBL and Composite log (no correction to openhole logs). SWI and perforated 5316-5329' MD with 630 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 680 to 960 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed 1.8 bbls water to surface with gun (cum total of 9.8 BW at 11 :30 AM). Armed 2-3/8" carrier and took lubricator to tree. RIH with 4' perforating gun. Correlated depth with CBL and Composite log (no correction to open hole logs). SWI and perforated 5204-5208' MD with 780 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 780 to 980 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Producedlswabbed 3.4 bbls water to surface (cum total of 13.2 BWat 13:30 AM). Armed 2-3/8" carrier and took lubricator to tree. RIH with 10' perforating gun. Correlated depth with CBL and Composite log (no correction to open hole logs). SWI and attempted to perforate 5084-5094' MD with 650 psi surface WHP. No positive indication the gun fired. Opened well back to sales at LP. POOH with guns taking appropriate measures to lay down and disarm a live perf gun. Went to radio silence at 200' from surface. Produced/swabbed 4.4 bbls water to surface (cum total of 17.6 BW at 15:00 AM). Printed: 2/14/2006 2:20:29 PM . . Ma r athonO,il.C^^o^m.,pa^n y ", .... .... ....'<"..........................">,,............. ........ Operations SÙt'nmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2005 15:00 - 15:15 15:15 - 15:45 15:45 - 16:00 16:00 - 16:30 FALLS CREEK 4 FALLS CREEK 4 RECOMPLETION NABORS DRILLING NABORS DRILLING To Hours 0.25 0.25 16:30 - 18:00 1.50 RURO - ELEC CMPFLW 12/2/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPPRF 08:30 - 10:00 1.50 RURO - ELEC CMPPRF 2/4/2006 10:00 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 19:00 09:30 - 10:00 10:00-11:15 11:15-12:00 12:00 - 12:30 2.50 RUNPU ELEC CMPPRF 1.00 RURO_ ELEC CMPPRF 1.50 CMPPRF 2.00 RUNPU ELEC CMPPRF 2.00 RURO_ ELEC CMPPRF 0.50 SAFETY MTG_ CMPPRF 1.25 RURO_ ELEC CMPPRF 0.75 RUNPU SLlK CMPPRF 0.50 PULO_ EQIP CMPPRF Spud Date: 1/20/2004 End: Group: Start: 11/9/2005 Rig Release: Rig Number: 129 Description of Operatioíi- LO perf gun and disarmed firing head. No shots fired. Replaced PX-1 firing head. Armed 2-3/8" carrier and took lubricator to tree. RIH with 10' perforating gun. Correlated depth with CBL and Composite log (no correction to openhole logs). SWI and perforated 5084-5094' MO with 690 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 690 to 970 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Produced/swabbed 3.4 bbls water to surface (cum total of 21.0 BW at 17:00 AM). ROMO Expro Wireline. Plan to rig up again to finish perforating around November 16 or 17. Well producing 2530 Mcfd at 774 psi FTP at 1700 hrs. Held PJSM with Expro and MOC personnel. Reviewed Safe Work Permit and job hazards. MIRU Expro Wireline to run a real-time flowing BHP survey to try to identify water productive interval(s). Well producing 2550 Mscfd and - 50 BWPO at 640 psi FTP. Spotted equipment. MU wireline valve and flow tee to top of tree. MU 2.35" 00 fluted swage with 2.25" 00 centralizeer and CCL and pulled into lubricator. Took lubricator to wellhead. RIH with 2.35" swage and tagged up in Module #8 at 5570' WLM. Worked through and tagged up in Module #6 at 5939' WLM. Worked through and RIH to 7106' WLM. Tagged hard. WHP jumped from 650 to 800 psi. POOH with 400-500 Ibs overpull through Modules. POOH and LO lubricator. Found top 10-15' of wireline above control head was crimped and twisted. It appears that when the tool tagged at 7106' it was blown uphole a short distance. Cut off bad wire and reheaded rope socket. MU real-time P-T tool string and pulled into lubricator. Took lubricator to well. RIH with tool string with well making 2460 Mcfd at 640 psig FTP. Began logging at 4700'. Correlated depth with open hole log. Logged down until tagged at 7648' MO. FBHP at 1189 psig and FBHT at 97 deg F. POOH logging to 4700' MO. Pulled hard through perf modules varying weight from 300 Ibs underpull to 600 Ibs overpull. Temporarily stuck at -5800' MO. Worked tools and POOH. Weight fluctuations smoothed out after passing top module. Took 5 minute benches every 1000' to surface from 4000'. Falls Creek Compressor went down at 15:45 hrs and could not be restarted. Nothing wrong with the tool string when layed it down with lubricator. ROMO Expro Wireline. Left well flowing at 1500 Mcfd at 768 psi FTP. Held PJSM with Expro, Protechnics, and MOC personnel. Reviewed Safe Work Permit and job hazards. MIRU Expro slickline unit to run a Protechnics memory PL T across the non-EXCAPE perfs in this well. Well producing 2480 Mscfd and - 46 BWPO at 625 psi FTP. Spotted equipment. MU wireline valve and flow tee to top of tree. MU 2.25" 00 GR to 1.5" 00 sllickline tool string. Took lubricator to wellhead and pressure tested with WHP. Roundtripped 2.25" 00 gauge ring on slickline to 5516' KB. No problems. LD GR and PU Protechnics 1-11/16" memory PL T tool string (-19' Printed: 2/14/2006 2:20:29 PM . . M(irathon Oil Company Operations Summary Report 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/4/2006 FALLS CREEK 4 FALLS CREEK 4 RECOMPLETION NABORS DRILLING NABORS DRILLING C Sub ode Code Phase Spud Date: 1/20/2004 End: Group: Start: 11/9/2005 Rig Release: Rig Number: 129 Description of Operations 12:00 - 12:30 12:30 - 13:45 0.50 PULD EQIP CMPPRF OAL). 1.25 RUNPU SLlK CMPPRF RIH with PL T to 5000' and began down pass at 60 FPM. Logged down and up pass from 5000-5516' KB. Made passes at 90 and 120 FPM over same interval. Production was steady at 2400 Mcfd and 42 BWPD at 625 psi FTP. 0.75 RUNPU SLlK CMPPRF Conducted 5 minute "time-drive" surveys with PL T stationary for 5 minutes each at 5516',5450',5378',5350',5250',5150', and 5050'. POOH with PL T tools. 1.50 RURD_ ELEC CMPPRF RD lubricator and slickline unit. Left well flowing to sales through Pad compressor. Close out Work Permit, signed out. and left Pad. 13:45 - 14:30 14:30 - 16:00 Printed: 2/14/2006 2:20:29 PM · Alaskeness Unit ~ t Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 14, 2004 Attention: Howard Oakland Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 Hand Delivered RE: Marathon Falls Creek #4 Well Data CONFIDENTIAL Enclosed are the following CONFIDENTIAL data for the above referenced well: Paper Digital Daily Drilling Report & Daily Completion Report ............................................. X~.................. NA Well Completion Report.............................................................................. In Progress Directional Survey............................................................................................... X ~.....................X Test Results......................................................................................................... X -:-:.......................X Permit To Drill .................................................................................................... X...;...................... NA As-Built............................................................................................................... X ¿................... ..X Epoch Mud Log Data Report wi CD ................................................................... X é....................X ,./' CD of Well Logs (list of CD contents attached).................................................. ...........................X ttl L e-¿ 70 The Data View and Ree View viewer software for the Reeves well logs can be downloaded from their website at: http://www.reeves-wireline.com/. Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address. Thank you, q{~ Kaynell Zeman Technical Assistant Enclosures Received by: Date: (I ?L~ OW ! ~ ~ 0, ..~.) ;z () 1 - ..tÀ. I r¡::;/~ . .' .. . Falls Creek 4 Log Data . ~ Fe4JinalJeeves.las ~ Fe4_FinaUeevesJ)lots.dpk ~ Fe4_neutron-den~tD_shoe.las ~ Fe4 _ veeJinal.las 1,654 ICB LAS File l,4B3 ICB DPIC File l,74B ICB LAS File 602 ICB LAS File Falls Creek 4 Directional Survey 21512004 B:52 PM 2/5/20048:52 PM 2/5/20049:28 PM 2/6/2004 1 :07 AM Falls Creek 4 Test Results Falls Creek 4 As Built Falls Creek 4 Mud Log Data WillI Dml Data WillI LAS File WillI Morning Reports WillI PDF Files WillI Remarks File WillI Well Report ~FC4 Remarks.las File Folder File Folder File Folder File Folder File Folder File Folder 457 KB LAS File 412121J1J4 1 :51J PM 4/2/21J1J4 1: 51J PM 4/2/2004 1 :50 PM 4/2J21J1J4 1 :50 PM 412/201J4 1 :51J PM 4/2/2004 1 :50 PM 3/17/20047:25 PM . . ,- " " ~ / / CONTROL POINT #1 N: 2,269,451.20 E: 239,837.18 ELEV. .. 249.72' = / FALLS CREEK PAD AS-BUlL T /~Tf~~~ ~,¡,~; ,lit %f~~J~j r( r( ¡ (î !J ~ FOREST / SCALE FOREST sr 1°1' FEET . / ~ 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ a ~ ~ N:2,269,700 / ~: 239,900 ~~\~ ~OWER POLE N 2269700 ~.. +E 240 400 f'\~~ r --ø- """-::::;;;c .\.._- 9'f'e-'~ 'ò"\J- / 4 .{'r ~".",,,, ~ Y:-~ ~Ø"~~C:; /'#~ LEGEND EASEMENT I SETBACK BOUNDARY ---- PROPERTY LINE .~-':-:;;--_.--- CONTOURS @) 8:,. 8 ø GAS I WATER WELl LOCATION SEPTIC VENTS PHONE PEDESTAL HEA POWER TRANSFORMER o BOLLARDS FOREST NOTES N: 2,269,300 -t=: 239,800 1. BASIS OF COORDINATES IS NGS MONUMENT L82 AT MILEPOST 119.1 Of THE STERLING HIGHWAY. LATITUDE AND LONGITUDE VAlUES ARE FROM THEAOOT&PF GEOREFERENCJNG PROJECT GPS CONTROL POINTS. 2. BASIS OF VERTICAL CONTROL WAS FROM NGS MONUMENT L82 AT MILEPOST 119.1 OF THE STERLING HIGHWAY, ELEVATION"'346.15 FEET (NAVD8B). 3. FIELO WORK CONDUCTED MOST RECENTLY ON APRIL 23, 2003. LOCATIONS & OBJECTS HEREON REPRESENT As-BUIL T CONDITIONS, THAT DATE. >- 0 ~ z « « a... a... z ¿ 0 !:i 0 ¡::: , « 5 5 U c.:: "? if --.J 0 V) a --' « ~ 0 a... X >- Z w >- ~ ~ ::J I 0 w U I w « c.:: u.. fo- (J 8 « V) ~ a::: --' ~ « --' « ~ ~ ¿ u.. I I! ~I å ~. ~ 0 '" 9 0 >- ~ ci ~ ~ IL ~ 0 J: W C) C) I o . Z N a C) ~ t;~7~ W 2 ~ ~~~~ ::ï ~ ~~!i a:: '9 '" ~~~t w i:~ I- ~~ o~. (J) !!;; ¡:;;¡fi ~ ~¡~t j ~ N' ~~¡¡~ :f ~c:i~:::t: N: 2,269,300 ~"f E: 240,500 + I O¡ '. ~ ~ ~ ~ ~ Ii COMPANY: Marathon Oil Company HALLIBURTON ENERGY SERVICES (~Ø):==nv FIELD: Falls Creek SURFACE TESTING REPORT HALLI au RTCN LEASE: Falls Creek . WELL#: 4 , CO. REP.: Jim Thompson ~ l jREMARKSlil~7~EL:~:~D~~~~~:{€~rB¡;: SE.I?ARATQRcONDITIONS r TOTAL GAS,· """,1 ·"""<:TQTALWATER 3/29/04 5:30 STATIC ...¡¡Ø~=~)m·'·'·¡~~~·····I;·P:[~jE G=i~~VJI·7S..AA~E ~Ä~.¿~M·I·(::))7~~r~~~!· ~ØMT~ i:iliMM: (~$I~~< i6w/dålif f66íM ,..._..1.., "'- I.....- -- - - It t )I' ~TLT þ 1'J11 lIT --" o. J " ..,""" 3/27/0417:30 BHP--1219 psi 10 64 100 0.00 208.48 3/27/04 18:30 BHP--1219 psi 10 0 64 100 198.00 216.73 BHP--1286 psi, Flowing well directly .7/0419:30 into aas buster 5 0 64 100 0 0 0 0.000 0.000 0.00 0.00 211.92 225.56 BHP--1285 psi, Flowing well directly /27/0420:30 into aas buster 5 0 64 100 0 0 0 0.000 0.000 0.00 0.00 193.44 233.62 BHP--1287 psi, Flowing well directly 3/27/04 21 :30 into lias buster 12 0 64 100 0 0 0 0.000 0.000 0.00 0.00 465.84 253.03 BHP--1287 psi, Flowing well directly 3/27/0422:30 into aas buster 15 0 64 100 0 0 0 0.000 0.000 0.00 0.00 8.6 466.08 272.45 BHP--1289 psi, Flowing well directly 3/27/0423:30 into aas buster 35 0 64 100 0 0 0 0.000 0.000 0.00 0.00 731.28 302.92 BHP--1291 psi, Flowing well directly 3/28/04 0:30 into lias buster 45 0 64 100 0 0 0 0.000 0.000 0.00 0.00 8.6 762.48 334.69 BHP--1292 psi, Flowing well directly 3/28/04 1 :30 into lias buster 55 0 64 100 Trace of gas at gas buster 0.000 0.00 0.00 847.20 369.99 BHP--1278 psi, Flowing well directly 3/28/04 2:30 "as buster 95 0 64 100 Trace of gas at gas buster 0.000 0.00 0.00 8.6 1057.44 414.05 3/28/04 3:30 BHP-1126 psi, Turning into Hp Sep. 220 0 64 100 1482.48 475.82 3/28/04 4:30 BHP--1101 psi 375 0 32 100 270 12 60 1.000 0.600 377.14 15.71 2232.00 568.82 3/28/04 5:00 BHP-1102 psi 375 68 0 32 100 280 12 60 1.000 0.600 384.03 23.71 1392.00 597.82 BHP--1101 psi,Drained sand trap 3/28/04 5:30 aDD. 6 oz of sand rec 375 68 0 32 100 270 12 66 1.000 0.600 374.64 31.52 624.00 610.82 /28/04 6:30 BHP--1102 psi 425 68 0 32 100 280 12 68 1.000 0.600 380.63 47.38 696.00 639.82 BHP--1101 psi, drain sand trap, trace 3/28/04 7:00 sand 450 66 0 32 100 300 12 68 1.000 0.600 405.94 55.84 960.00 715.51 3/28/048:00 BHP--1102 psi, adjust back pressure 525 66 0 32 100 345 13 68 1.000 0.562 453.17 74.72 648.00 742.51 3/28/04 9:00 BHP--1101 psi, purge BHP line 525 67 0 32 100 285 44 73 1.000 0.562 754.22 106.14 624.00 768.51 BHP--1045 psi, dump sand trap, 3/28/04 10: 00 a""mox 1 liar frac sand 525 68 0 32 100 330 46 82 1.000 0.562 821.53 140.38 624.00 794.51 3/28/04 11 :00 BHP--1045 psi 565 68 0 32 100 365 50 90 1.000 0.562 893.29 177.60 624.00 820.51 BHP--1043 psi, dump sand trap, 3/28/0412:00 aDDmox1cuDfracsand 600 66 0 32 100 420 57 96 1.000 0.562 1017.38 219.99 456.00 839.51 3/28/0413:00 BHP--1045 psi 650 68 0 32 100 450 60 91 1.000 0.562 1086.99 265.28 408.00 856.51 3/28/04 14:00 BHP--1045 psi, purge BHP line 665 69 0 32 100 480 64 87 1.000 0.562 1165.60 313.84 8.3 31500 264.00 867.51 BHP--1084 psi, dump sand trap, 3/28/0415:00 aDDmox 1/4 CUD frac sand 650 66 0 32 100 420 64 82 1.000 0.562 1094.68 359.46 8.3 31500 336.00 881.51 Page 1 ^èJ)~).À.l COMPANY: Marathon Oil Company HALLIBURTON ENERGY SERVICES ¡!'~~:I:~v FIELD: Falls Creek SURFACE TESTING REPORT HALLiBURTON lEASE: Falls Creek . WEll#: 4 ~ CO. REP.: Jim Thompson t I jF}"'-I~1;~=';fr~~~f~~~ SEPAAATORCQNPrJ"IPNS . . "",:::'::::f::::: TOTAL/GAS ill TOTALWATER 3/29/04 5:30 DIFF TEMP Ø~.lFj¢E $Ä$$AAŸ (AA$.MTe ~Ä$.êijMM.I..wr...CHtORIDES H2O RATE CUMM. IlTllJllitrel IbWidJiyf tllbh& 3/28/0416:00 BHP--1045 psi 665 65 0 32 100 505 70 90 1.000 0.562 1247.20 411.42 8.3 31500 336.00 895.51 3/28/0417:00 BHP--1044 psi 750 64 0 32 100 600 80 93 1.000 0.562 1453.30 471.98 8.3 31500 216.00 904.51 3/28/0417:30 BHP--1044 psi 750 64 0 32 100 600 80 88 1.000 0.562 1461.77 502.43 8.3 31500 336.00 911.51 BHP--1114 psi dumped sand 3/28/0418:30 trao:trace amt.of solids 765 62 0 32 100 630 84 88 1.000 0.562 1536.79 566.46 8.3 31500 240.00 921.51 .8/0419:30 BHP --1105 765 60 0 32 100 630 84 86 1.000 0.562 1540.45 630.65 8.3 31500 216.00 930.51 /28/0420:30 BHP --1106 770 60 0 32 100 660 86 86 1.000 0.562 1597.45 697.21 8.3 31500 180.00 938.01 BHP --1109 ;dumped sand trap, 3/28/04 21 :30 trace solids. 800 58 0 32 100 685 90 85 1.000 0.562 1668.78 766.74 8.3 31500 276.00 949.51 3/28/0422:30 B.H.P.1130 825 58 0 32 100 700 92 85 1.000 0.562 1706.79 837.86 8.3 31500 120.00 954.51 B.H.P.1159, Flowing gas to 3/28/0423:30 oroduction Gas Gravitv .520 860 58 0 32 100 720 94 85 1.000 0.520 1809.08 913.24 8.3 31500 144.00 960.51 3/29/04 0:30 B.H.P.1175;Gas gravity .520 875 58 0 32 100 780 104 86 1.000 0.520 1982.76 995.85 8.3 192.00 968.51 B.H.P.1178;dump sand trap trace 3/29/04 1 :30 amt. of solids 875 58 0 32 100 780 110 86 1.000 0.520 2039.25 1080.82 8.3 31500 96.00 972.51 B.H.P.1186; Flowing gas to 3/29/04 2:30 Production. 890 58 0 32 100 780 110 86 1.000 0.520 2039.25 1165.79 8.3 144.00 978.51 B.H.P.1188; Flowing gas to 3/29/043:30 Production~ oas aravitv .520 890 56 0 32 100 780 112 86 1.000 0.520 2057.74 1251.53 8.3 31500 192.00 986.51 B.H.P.1189; Flowing gas to 3/29/04 4:30 Production. 895 56 0 32 100 780 120 86 1.000 0.520 2130.11 1340.28 8.3 216.00 995.51 B.H.P.1189; Flowing gas to 3/29/04 5:30 Production. 895 56 0 32 100 785 122 86 1.000 0.520 2155.09 1430.08 8.3 31500 96.00 999.51 3/29/04 6:30 B.H.P.1190 psi 895 56 0 32 100 785 125 86 1.000 0.520 2181.48 1520.97 8.3 31500 144.00 1005.51 B.H.P.1197 psi,purge BHP,dump 9120047:30 sand trao.traces frac sand. 900 56 0 32 100 785 124 86 1.000 0.520 2172.72 1611.50 8.3 31500 216.00 1014.51 3/29/20048:30 B.H.P.1218 psi. 900 57 0 32 100 785 130 86 1.000 0.520 2224.78 1704.20 8.3 31500 96.00 1018.51 3/29/2004 9:30 B.H.P.1219 psi. 905 58 0 32 100 785 133 86 1.000 0.520 2250.36 1797.97 8.3 31500 144.00 1024.51 B.H.P.1217 psi.dump sand trap, 3/29/200410:30 traces frac sand. 905 58 0 32 100 785 132 86 1.000 0.520 2241.86 1891.38 8.3 31500 192.00 1032.51 3/29/2004 11 :30 B.H.P.1198 psi. 900 57 0 32 100 780 136 86 1.000 0.520 2267.97 1985.88 8.3 31500 57.60 1034.91 3/29/200412:30 B.H.P.1199 psi. 900 59 0 32 100 780 138 86 1.000 0.520 2284.63 2081.07 8.3 31500 254.40 1045.51 B.H.P.1198 psi. WHP at gauge at 3/2912004 13 :30 wellhead 1000 59 0 32 100 780 140 86 1.000 0.520 2301.16 2176.95 8.3 31500 96.00 1049.51 3/29/2004 14:30 B.H.P.1198 psi. 1000 59 0 32 100 780 142 86 1.000 0.562 2242.82 2270.40 8.3 31500 96.00 1053.51 B.H.P.1196 psi.dump sand trap, 3/2912004 15:30 traces frac sand 1000 60 0 32 100 780 144 86 1.000 0.562 2260.61 2364.59 8.3 31500 144.00 1059.51 B.H.P.1196 psi.16:45 increase choke 3/29/200416:30 to 36/64 1000 60 0 32 100 780 148 86 1.000 0.562 2291.87 2460.09 8.3 31500 96.00 1063.51 Page 2 COMPANY: Marathon Oil Company HALLIBURTON ENERGY SERVICES :i,~~:I.·==.W FIELD: Falls Creek SURFACE TESTING REPORT HALL~ au RYCN LEASE: Falls Creek WELL#: 4 .. . CO. REP.: Jim Thompson . I j/tœ"""""i~æ¡i1i~.~I~ij:¡: SEPAAATQRCQNPlr!QNS.....·· T TOTAL GAS TOTAL WATER 3/29/04 5:30 DIFF tåMP.....I.ø~mm:iå. 6A$(;~Avl~A$AAtå ~A$cijMM. WT; c:L:R'[)~1··~2Ø·~~··liuMi· bbls 3/29/200417:30 B.H.P.1165 psi. 875 60 0 36 100 780 30 86 1.500 0.562 2356.68 2558.28 8.3 31500 192.00 1071.51 B.H.P.1155 psi.dump sand trap 3/29/2004 18:30 traces frac sa nd 875 58 0 36 100 780 31 86 1.500 0.562 2395.65 2658.10 8.3 31500 96.00 1075.51 3/29/2004 19:30 B.H.P.1155 psi. 875 58 0 36 100 780 31 86 1.500 0.562 2395.65 2757.92 8.3 31500 120.00 1080.51 3/29/2004 20:30 B.H.P.1142 psi. 850 56 0 36 100 780 32 86 1.500 0.562 2434.01 2859.34 8.3 31500 96.00 1084.51 B.H.P.1140 psi. 21:45 increase ./200421 :30 choke to 40/64 860 56 0 36 100 780 33 86 1.500 0.562 2471.76 2962.33 8.3 31500 192.00 1092.51 B.H.P.1133 psi.Dumped sand trap 9/2004 22:30 slinht trace of solids noted. 850 56 0 40 100 780 33 90 1.500 0.562 2459.35 3064.80 8.3 31500 96.00 1096.51 3/29/200423:30 B.H.P.1133;Gas Gravity .562. 875 56 0 40 100 780 36 86 1.500 0.562 2581.74 3172.37 8.3 31500 96.00 1100.51 3/30/2004 0:30 B.H.P.1133 875 56 0 40 100 780 36 86 1.500 0.562 2581.74 3279.95 8.3 31500 120.00 1105.51 B.H.P.1131 ;Dumped sand trap, 3/30/2004 1 :30 trace of solids noted. 875 56 0 40 100 785 36 88 1.500 0.562 2584.07 3387.62 8.3 31500 96.00 1109.51 3/30/20042:30 B.H.P.1133 875 56 0 40 100 785 36 86 1.500 0.562 2590.07 3495.54 8.3 31500 144.00 1115.51 B.H.P.1130;Dumped sand trap ,trace 3/30/20043:30 of solids noted. Gas aravitv .562 875 56 0 40 100 785 36 86 1.500 0.562 2590.07 3603.45 8.3 31500 144.00 1121.51 3/30/2004 4:30 B.H.P.1134 875 56 0 40 100 785 38 86 1.500 0.562 2661.65 3714.36 8.3 31500 144.00 1127.51 . CONf···Ir\t~JT!t^l . . .~. i~¡~""~~ ~ nt\ Page 3 . ~1f~1fŒ mJ~ t%~~~æ~ / AI',ASIiA OIL AlQ) GAS / CONSERVA'DON COltDllSSION . I . FRANK H. MURKOWSKI, GOVERNOR Ken D. Walsh Senior Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: NinilchikjFalls Creek #4 Sundry Number: 305-330 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 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. DATED thisæ day of October, 2005 Encl. e/4 If), l~ ,05 I STATE OF ALASKA I ALAS Oil AND GAS CONSERVATION COMMI ION APPLICATION FOR SUNDRY APPROVALS ~~t= ì ~L u~ (, lO~S -C/EI \it" OCT 2 /1 2005 20 MC 25.280 AI::IJ:k;¡ Oil & Gas r.lm!; Le_ 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate L::.J .-' Waiver U AnCh(}fa~¿her U Alter casing D Repair well D Plug Perforations D Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: / \d ,,¡y- æ( 5. Permit to Drill Number: Marathon Oil Company Development ~ Exploratory 203-221 -~ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 1949, Kenai, AK 99611-1949 50-133-2053300 ./ 7. KB Elevation (ft): 9. Well Name and Number: Ninilchik Unit: Falls Creek #4 ./ 261.5 8. Property Designation: 10. Field/Pools(s): ADL 590 Ninilchik Unit/Beluga and Tyonek 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7910 6047 7829 5974 Casing Length Size MD / TVD Burst Collapse Structural Conductor 101' 20" 101' 101' 2410 psi 770 psi Surface 1840' 13-3/8" 1840' 1550' 3450 psi 1950 psi Intermediate 4888' 9-5/8" 4888' 3302' 6870 psi 4750 psi Production 7866' 3-1/2" 7866' 6008' 10160 psi 10540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): rUbing Size: I~Ubing Grade: Tubing MD (ft): 5516-7654' Gross 3873-5816' Gross 3-1/2" L-80 7866' Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: / ~ . '4/~ Detailed Operations Program 0 BOP Sketch D Exploratory ~ evelopment -B- Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/1/2005 Oil 0 Gas 0 / Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken D. Walsh Printed Name Ken D. Walsh ~ fì Title Senior Production Engineer Signature ( (1.AA h ~ W ^ \J A V. Phone 907-394-3060 Date 1 0/20/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: OOf) ~ 33(:) Plug Integrity 0 BOP Test D Mechanical Integrity Test 0 Location Clearance 0 Other: S"b~77ßÝir~ 4D 4 RBDMS 8F" 2 6 2DD5 APPROVED BY ,ø/~ í¡( Approved bY{ /1 fA COMMISSIONER THE COMMISSION Date: VVlJ '--'- , , Form 10-403 Revised 07/2005 ORIGINAL Submit in Duplicate . . Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564·6305 Fax 907/564-6489 October 19, 2005 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 add Tyonek perforation in the Falls Creek #4 well. This well is an active Beluga/Tyonek gas producer. Also attached for your records is the current well schematic and proposed procedure. Please note that provisions have been made in the procedure to set a casing patch to isolate ./ excessive water flow after perforating the new intervals, if required. If you would like any other information, please contact me at 394-3060 or kdwalsh@marathonoil.com. Sincerely, IÚM- b,\0~ Ken D. Walsh Senior Production Engineer Enclosures . . MARATHON OIL COMPANY ALASKA REGION Ninilchik Unit Falls Creek #4 2005 Beluga Recompletion Procedure WBS# ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: · This procedure covers work to obtain a flowing temperature-pressure survey and to add new Tyonek perforations. · The first perf gun run for each interval listed below should be no longer than 18' to ensure that a casing patch can be run to isolate an unexpected water flow. Have 3-1/2" casing patch equipment readily available to install, if necessary. · All flow tests are to be made through the production facilities. If excessive water production is encountered, MIRU the MOC flow back equipment including chicksan, open-top tank, and choke manifold to handle the water until a casing patch can be installed. Proposed New Beluaa Perforations. 60% Drawdown SBHP (0.57 sp gr gas) MD Foota2e TVD (0.469 psi/ft) FBHP FTP 5465-5478' 13ft 3827-3839' 1800 psi 720 psi 661 psi 5383-5416' 33 ft 3753-3783' 1774 psi 71 0 psi 653 psi 5360-5376' 16 ft 3732-3746' 1757 psi 703 psi 647 psi 5316-5329' 13 ft 3692-3704' 1737 psi 695 psi 640 psi 5204-5208' 4ft 3590-3594' 1685 psi 674 psi 623 psi 5074-5094' 20 ft 3472-3490' 1637 psi 655 psi 607 psi 4992-5036' 44 ft 3397-3437' 1612 psi 645 psi 598 psi 4946-4956' 10 ft 3355-3364' 1578 psi 631 psi 586 psi 1. Deliver Rental Eauipment. Deliver light plant and manlift to location. Blow well down to unload produced water the day previous to perforating the well. 2. Run 2.75" aD aauae ring on MIRU Pollard slickline to PBTD (last tag with 2.0" DD bailer was 7634' MD). RDMO Pollard slickline. 3. Perforate Beluaa. MIRU Expro wireline service with full lubricator and pressure control equipment. Hold PJSM to review Safe Work Permit and operational hazards. Produce well at line pressure (about 800 psi FTP) while running in the hole with perforating guns. PU and RIH with CCl and 2.375" HSD guns with 6 SPF, 60 Page 2 of2 . . degree-phased, T AG-2375-402NTX charges, and PX-1 firing head (if Pad activities warrant, use conventional 008 firing head). Correlate depth to Composite Openhole\Cased Hole log provided by David Brimberry incorporating Reeves Quad Combo and CBT/GRlCCL. Shut well in and immediately perforate 5465-5478' MO with 800 psi WHP. While PUH with perf guns, leave well shut in for 10 minutes to monitor pressure build. Continue POOH with guns and begin opening well up to sales. Continue perforating the Beluga working top down from the list above. / NOTE: Monitor flow rate and FTP to determine if excessive water flow is coming from this new interval. If water flow is excessive, RU Expro and set a casing patch across the interval. 4. Obtain Real-time Flowina Temperature-Pressure Survey. Make arrangements with the NGF Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a 2.75" OD gauge ring to PBTO. RIH with CCL and 1- 11/16" real time Spartec pressure-tem perature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to PBTO (bottom perf is at 7654' MO). Correlate depth and POOH logging to about 100' above fluid level. POOH taking 5 min benches every 2000'. ROMO Expro Wireline. 5. RDMO and release eQuipment. If tanks and flow back equipment were used to handle excessive water flows while perforating, transport fluid from tanks to the G&I Plant for disposal and ROMO flowback iron and tanks. Release all rental equipment to vendors. , 6. FLOW TEST WELL TO SALES AT LP. The unloading rate up 3-1/2" casing in a vertical well is 2.44 MMCFO @ 800 psig FCP. The unloading rate for the 64 degree tangent section in this well is 3.0 MMCFO @ 800 psig FCP. Flow well to sales observing recommended drawdown rates. When site- based compression is available, limit maximum surface FTP to 650 psig to achieve a 60% drawdown limit. CONTACTS Ken Walsh: 907 -283-1311 (w) 907-394-3060 (c) David Brimberry: 713-296-2265 (w) 713- 408-0703 (c) Ben Schoffmann: 907-565-3035 (w) 907-268-0122 (p) Clyde Scott: 713-296-2336 (w) Ninilchik Operators: 907-260-7660 or 907-567-3248 (Susan Dionne Pad) KGF Operators: 907-283-1305 Perforation Information: 2.375" 00 HSO guns loaded with 6 SPF, 60 degree-phased, TAG-2375-402NTX charges. API target performance is 0.22" entrance hole and 20.58" penetration. Maximum gun swell in air is 2.575" 00. FC #4 Beluga Recompletion Procedure KDW - 10/20/2005 9:30:06 AM API: 50-133-20533 RT-GL: 16.50' RT-THF: 16.20' 1842'FSL,2842'FVVL,Sec.6, T1N, R12W, S.M. Tree cnx :::: 4-3/4" Otis ¡TOC (est.) - 300' above 9-5/8" shoe' I Excape System Details - 8HP monitoring line volume tank located from 5435' - 5471' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 5543' Module 8 - 5596' Module 7 - 5857' Module 6 - 5947' Module 5 - 6054' Module 4 - 6462' Module 3 - 6689' Module 2 - 7327' Module 1 - NA Well Name &. Number: County or Parish: Perforations (MD) Angle/Perfs BHP: Dated Completed: Prepared By: FC#4 TO - 7910' P8TD - 7829' FC#4 Kenai Surface Casing: 13-3/8", 68 ppf, K-55, BTC @ 1840' Cmt wI 434 sks of class G at 12.5 ppg Int. Casing: 9-5/8",47 ppf, L-80, BTC @ 4888' Cmt wI 400 sks of class G lead at 12.5 ppg & 175 sx of class G tail at 13.5 ppg Prod. Tubinq: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 7866' Cmt wI 850 sks of class G at 13.5 ppg Excape System Details - 9 Excape modules placed . Green control line fires bottom 1 module - Red contolline fires top 8 modules - Ceramic flapper valves below each module except for Module 1 Perfs MD (RK8): Module 9 - 5516'-5526' Module 8 . 5570'-5580' Module 7 - 5832'·5842' Module 6 . 5922'·5932' Module 5 - 6028'·6038' Module 4 - 6436'-6446' Module 3 . 6664'-6674' Module 2 - 7300'-7310' Module 1 ·7644'·7654' Lease: State/Provo Alaska (WD) USA 6% KCL Last Revison Date: 10/19/2005 KDW e . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Marathon Oil Company May 12, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Completion Report 10-407 for permit 203-221 Field: Falls Creek Gas Field / Beluga & Tyonek Well: FC - 4 Dear Mr. Aubert, Enclosed please find the Well Completion Report with associated attachments for Falls Creek well No.4. This well has been completed cased hole with a 3.5" Excape monobore production string to surface. I apologize for the delay in getting this completion notice to you. Should you require further information, I can be reached at 907-529-0524/713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, .~ ames R. Thompson Sr. Completions Engineer Enclosures: Completion Report Directional Survey Operations Summary Wellbore Diagram RECEIVED MAY 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage nOlh1f\JAL e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. WeU Status: OilD Gas~ pluggedDAbandoned D Suspended D WAGD 1 b. WeU Class: 2OMC25.105 2OMC25.110 Development Exploratory IE] GINJ D WINJD WDSPLD No. of Completions 1 Other Service Stratigraphic Test D 2. Operator: 5. Date Comp., Susp., Permit to DriN Number: Name: Marathon Oil Company or Aband: 312612004 v 203-221 3 Address: 6. Date Spudded: API Number: P.O. Box 196168, Anchorage, AI< 99519-6168 1/2012004 / 50- 133-2053300 48. Location of WeN (Governmental Section): 7. Date TD Reached: ~'jJÞ 14. WeU Name and Number FaNs Creek No.4 Surface: 1,842' FSL, 2,842' FEL, Sec. 6, T1 N, R12W, S.M. 8. KB Elevation (ft.): ,,', ¿,;;; ~r 15. FieIdlPool(s): 261.5 Top of Productive 1,092' FSL, 693' FEL, Sec. 1, T1N, R12W, S.M. 9. Plug Back Depth (MD + Beluga & Tyonek Horizon: ~4,,1 TVD): /3W 7829' MD 1 5974' TVD Total Dapth: 775' FSL, 1,892' FEL, Sec. 1, T1 N, R';;(i. S.M. l,i' 4b. Location of WeN (State Base Plane Coordinetes): 10. Total Depth (MD+TVD): 18. Property Designation: 7910' MD 1 6047' TVD " ADL590 " Surface: x- 239,980.900 " y- 2,269,393.620 Zone- 11. Depth where SSSV Set: 17. Land Use Permit: NA TPI x- 236,833.980 y- 2,268,711.400 Zone- NA feetMD 19. Water Depth, if Offshore: 20. Thickness of Permefr05t: Total Depth x- 235,628.860 y- 2,268,420.870 Zone- ~ NA feet MSL NA 18. Directional Survey: Yes~ NoD 21. Logs Run: SP/GR-IEL-Dansity/Neutron-Sonic-Single Arm Caliper 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20' 133.0 K-55 0 101 0 101 Driven NA Na 13-318' 68.0 K-55 0 1840 0 1550 16' 434 sx NA 9-5/8' 47.0 L-80 0 4888 0 3302 12-1/4' 575 sx NA 3-1/2' 9.3 L-80 0 7886 0 6008 8-1/2' 850 sx 73,000 23. Perforations Open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; if none, state 'none'): SIZE DEPTH SET (MD) PACKER SET (MD) MD: 5516-5526, 5570-5580, 5832-5642, 5922-5932, 6028-6038, 6436-6446, 3-1/2' 7886 NA 6664H6674, 7300-7310, 7~7654 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED TVD: 3873-3882,3922-3931,4160-4169,4241-4251,4338-4347,4709-4718, See No. 23 30,200 to 32,400 Ibs 20140 Ottawa Sand 491~25,5495-5504,5807-5816 26. PRODUCTION TEST Date of First Production: 2/2/2004 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas- MCF: Water-Bbl: Choke Size: IGaS-Oil Retio: 415/2004 24 Test Period -~ NA NA NA 4OI64th NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Water-Bbl: oil Gravity - API (carr): Press: 900 0 24-Hour Rall-~ NA 3495 34 NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if nessary). Submit core chips; if none, state~ RECEIVED COMPLETIOf\t..¡ one 13~ê6f ORIGINAL MAY 1 3 2004 ~n v~·_· "Ü , 2"" Alaska Oíl & Gas Con~. ... l::._,,"'::_.';", _ ,.. IRBQMS BFL on Anchorage . r t, JJN 1i 4 1004 Form 10-407 Revised 412003 CONTINUED ON REVERSE SIDE e e 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME Me TVO Include and briefly Summarize test results. List intervals tested, and attach detailed SUppo,.¡¡ng data as necessary, If no tests were COnducted, state "None". None None RECEIVED MAY 1 3 2004 Ol & Gas Cons. Commission Alaska I Anchorage 30. Ust Of Attachments: Directional Survey, Operations SUmmary, Wellbore Diagram 31. t be.., "'''''...... ,,_ . """ "'" ""'" to ......." my __ Contact - - Printed Name James A. Th2!!JSpon Title Sr. ComoIetions Engineer - Signature ~ 'AJ2.-> f¿. M ..., Phone ';7-529-0524 / 713-296-27~ Date 5/1 ?/2004 :.::: - - .11 . - -, "'" """. -"""~ """"""'. ""'- "'" """'''' - """".... fog 00" _ ,,_ "'" _. _. .......... -..." "'-... - 1().407... _ """" "'" '..... ... '"""" """" _... downhole Well design is chanQed. INSTRUCTIONS """ '. -"'" "- "": "" -. "ole, -. "_·AItom....."" "-on,,,, "ole,.......... "Of., - to< -, """"'Iion. IN ","",. M""", """"'lion . ""... " . .... _... from ""'" "'" "'" _... ----""""""'- ---.."""",.... Item 4b: TPI (Top of ProdUCing Interval). "m. The "",..."", -lion.......,.". _ low low....,. u.. _.. "''''''''' fIN..... ""_....,,_ SP8Ces on this form and in any attachments. Item 20; True vertical thickness. """ 13: rbe ""'--""'toAOGcc -be 14 _ f""'-""23-fIo.ooJ. """'" - -.. ...",., to<....... "- _... _" "" _ _ __......... "'... cementing tOOl. ""...., «... "". -- to< -- -'''''' ""'" """ "'" _of ,_ -J. .,...." Item 1. """. Item 23 """'" -- ........ to< on1y... -of -" Item '" ,......,. __ """ fIN _ _ ..,,'., to be separately ProdUced, Showing the data pertinent to such Interval). 'tem "': """"" '" ""'_: ""","", "" Ü1\ Rod",- """"" """. """""-0, """ _. "",_ _., IN Other (explain). Item 27: If no COres taken, indicate "none.". Item 28: Ust al/ test infOrmation. If none, state "None". Fonn 10-407 ReVised 412003 e e MARATHON Oil Company Falls Creek Unit #1 FC-4 slot H Falls Creek Field Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-7910> svy70l2 Date printed Date created Last revised 3-Mar-2004 2l-Jan-2004 5-Feb-2004 Field is centred on 242770.254,0.000,999.00000,N Structure is centred on 242770.254,2267493.l44,999.00000,N Slot location is n60 12 l5.309,w15l 25 45.491 Slot Grid coordinates are N 2269393.620, E 239980.900 Slot local coordinates are 1840.36 N 2829.48 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ' e MARATHON Oil Company Falls Creek Unit #1,FC-4 Falls Creek Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 145.00 207.00 292.00 388.00 484.00 578.00 675.00 771.00 867.00 961.00 1022.00 1118.00 1212.00 1308.00 1404.00 1500.00 1595.00 1690.00 1787.00 1883.00 1979.00 2074.00 2170.00 2267.00 2361. 00 2458.00 2552.00 2649.00 2745.00 2839.00 2935.00 3031. 00 3127.00 3223.00 3318.00 3414.00 3510.00 3606.00 3700.00 3796.00 3892.00 3987.00 4083.00 4178.00 4274.00 4369.00 4465.00 4560.00 4655.00 10.60 14 .50 17.90 22.10 26.80 30.70 31.30 34.80 37.30 40.20 43.60 46.40 49.70 55.00 60.40 60.10 61.00 63.10 64.20 64.10 63.70 62.40 64.00 65.50 64.90 64.50 64.30 64.30 63.80 63.40 62.70 61.90 59.60 56.50 54.00 52.40 50.80 49.00 46.30 43.20 40.80 38.60 35.80 32.80 30.20 Azimuth Degrees 0.00 0.80 0.60 2.50 6.60 0.00 42.80 343.40 265.50 254.20 True Vert Depth 0.00 145.00 206.99 291.96 387.64 482.54 574.28 667.42 757.61 844.98 927.37 979.66 1060.12 1136.11 1210.97 1282.42 1350.29 1413.79 1471.80 1523.62 1571.26 1618.46 1662.98 1705.59 1747.88 1789.24 1833.20 1875.58 1916.96 1957.23 1997.40 2038.88 2080.51 2122.52 2165.20 2208.26 2252.88 2299.79 2350.58 2404.16 2461. 66 2521.29 2582.48 2647.15 2714.61 2785.95 2859.04 2935.50 3013.97 3094.96 SURVEY LI8TING Your ref Last revised R E C TAN G U L A R Dogleg COO R DIN ATE 8 Deg!100ft O.OON 0.74N 1. 37N 1. 65N 0.018 4.678 10.868 17.408 24.888 33.278 42.588 49.228 60.398 72.218 85.188 98.818 112.528 126.548 143.06S 163.108 182.42S 200.378 218.038 237.028 257.628 277.258 297.008 315.948 334.928 353.498 372 .038 391. 508 410.678 428.698 446.718 464.908 482.938 501.128 519.998 538.868 558.368 577.778 596.288 614.458 633.408 652.938 671.188 688.028 702.918 716.718 O.OOE 0.69E o .89E 1. 09W 8.49W 22.05W 41. 48W 67.74W 99.70W 138.52W 182.75W 213.46W 264.60W 318.63W 377.30W 439.93W 506.41W 575.65W 648.99W 728.46W 809.53W 891.18W 973.21W 1057.11W 1141.94W 1224.04W 1308.22W 1389.95W 1475.60W 1560.75W 1643.68W 1728.04W 1812.39w 1896.81W 1980.89w 2063.59W 2146.66W 2228.41W 2307.64W 2382.53W 2456.88W 2529.56W 2599.83w 2668.41W 2732.53W 2793.72W 2851. 59W 2907.12W 2958.54W 3006.21W 0.00 0.55 1.15 2.88 4.35 0.00 -0.84 -1.19 0.67 8.25 e Page 1 MWD <0-7910> 5-Feb-2004 Vert Sect G RID COO R D S Easting Northing 239980.90 239981.60 239981.82 239979.85 239972.42 239958.76 239939.19 239912.81 239880.69 239841.70 239797.28 239766.44 239715.08 239660.80 239601.87 239538.96 239472.21 239402.69 239329.01 239249.13 239167.67 239085.66 239003.27 238918.98 238833.74 238751.24 238666.66 238584.54 238498.50 238412.98 238329.67 238244.92 238160.17 238075.39 237990.95 237907.88 237824.45 237742.33 237662.71 237587.44 237512.69 237439.61 237368.96 237300.01 237235.51 237173.91 237115.67 237059.79 237008.06 236960.11 2269393.62 2269394.35 2269394.97 2269395.30 2269393.79 2269389.42 2269383.65 2269377.68 2269370.88 2269363.32 2269354.96 2269348.98 2269338.91 2269328.25 2269316.54 2269304.25 2269291.98 2269279.44 2269264.49 2269246.16 2269228.58 2269212.38 2269196.48 2269179.30 2269160.52 2269142.64 2269124.71 2269107.52 2269090.37 2269073.64 2269056.88 2269039.22 2269021. 86 2269005.65 2268989.43 2268973.02 2268956.77 2268940.33 2268923.17 2268905.91 2268888.00 2268870.15 2268853.16 2268836.46 2268818.89 2268800.67 2268783.67 2268768.02 2268754.23 2268741.45 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level). Bottom hole distance is 4459.42 on azimuth 256.16 degrees from wellhead. Vertical section is from wellhead on azimuth 256.45 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 249.10 254.70 257.10 256.60 258.80 257.50 258.10 257.30 258.00 257.10 258.30 258.40 258.70 256.00 255.70 257.50 257.70 258.00 256.50 256.20 256.90 256.70 257.20 257.80 257.60 257.20 256.80 257.60 258.30 257.50 257.70 257.80 257.10 256.10 255.60 255.00 255.10 255.40 254.90 252.10 252.50 252.50 253.80 253.90 253.80 4.24 4.34 3.57 4.38 4.99 22.53 42.87 69.93 102.75 142.46 4.20 1.11 3.67 2.70 3.08 187.64 219.05 271.38 32 6.68 386.75 3.64 2.92 3.48 6.01 5.57 450.84 518.67 589.27 664.44 746.40 1. 66 0.95 2.23 1.81 0.30 829.74 913.32 997.20 1083.22 1170.51 0.79 1.35 1. 77 1.64 0.65 1254.92 1341. 39 1425.28 1513.00 1600.12 0.57 0.43 0.75 0.84 0.85 1685.09 1771. 67 1858.16 1944.45 2030.41 0.76 0.84 2.48 3.35 2.70 2115.08 2200.05 2283.79 2365.24 2442.46 1. 74 1. 67 1. 91 2.84 3.87 2519.31 2594.52 2667.17 2738.09 2804.87 2.52 2.32 3.03 3.16 2.74 2868.93 2929.47 2987.40 3040.88 3090.46 e e MARATHON Oil Company 5URVEY LI5TING Page 2 Falls Creek Unit #1,FC-4 Your ref MWD <0-7910> Falls Creek Field,Kenai Peninsula, Alaska Last revised 5-Feb-2004 Measured Inclin Azimuth True Vert R E C T A N G U LA R Dogleg Vert G RID C o 0 R D 5 Depth Degrees Degrees Depth C 0 0 R D I N A T E 5 Deg/l00ft Sect Easting Northing 4751.00 27.70 253.80 3178.96 729.685 3050.83W 2.60 3136.87 236915.22 2268729.45 4845.00 24.90 256.20 3263.22 740.505 3091. 04W 3.19 3178.50 236874.79 2268719.49 4941. 00 24.20 256.80 3350.54 749.815 3129.82W 0.77 3218.38 236835.82 2268711.01 5037.00 24.10 256.00 3438.14 759.045 3168.00W 0.36 3257.66 236797.46 2268702.60 5132.00 24.80 257.60 3524.62 768.015 3206.28W 1.01 3296.97 236758.99 2268694.45 5228.00 24.50 255.70 3611.88 777.265 3245.23W 0.88 3337.01 236719.85 2268686.04 5323.00 24.40 254.30 3698.36 787.435 3283.21W 0.62 3376.31 236681.67 2268676.68 5419.00 25.50 256.60 3785.40 797.595 3322.40W 1.53 3416.79 236642.27 2268667.37 5514.00 25.30 255.40 3871. 22 807.445 3361.94W 0.58 3457.54 236602.53 2268658.36 5609.00 25.10 255.70 3957.18 817.545 3401.11W 0.25 3497.98 236563.15 2268649.11 5705.00 24.60 255.40 4044.29 827.605 3440.17W 0.54 3538.32 236523.88 2268639.88 5801.00 24.90 254.40 4131.47 838.075 3478.98W 0.54 3578.50 236484.86 2268630.25 5897.00 24.60 253.00 4218.65 849.355 3517.55W 0.69 3618.64 236446.06 2268619.80 5992.00 24.10 253.10 4305.20 860.775 3555.02W 0.53 3657.74 236408.36 2268609.18 6088.00 24.90 252.80 4392.56 872.445 3593.08W 0.84 3697.48 236370.06 2268598.33 6184.00 25.00 253.40 4479.60 884.225 3631. 82W 0.28 3737.90 236331.07 2268587.39 6280.00 24.70 254.20 4566.71 895.475 3670.56W 0.47 3778.20 236292.10 2268576.96 6376.00 24.20 255.50 4654.10 905.865 3708.91W 0.77 3817.92 236253.53 2268567.40 6470.00 24.40 256.90 4739.77 915.085 3746.48W 0.65 3856.60 236215.78 2268558.98 6566.00 24.70 255.40 4827.10 924.645 3785.20W 0.72 3896.48 236176.86 2268550.26 6661.00 25.00 255.70 4913.30 934.605 3823.86W 0.34 3936.40 236138.00 2268541.13 6757.00 24.50 255.30 5000.48 944.665 3862.77W 0.55 3976.58 236098.88 2268531.91 6853.00 23.90 255.00 5088.04 954.745 3900.81W 0.64 4015.93 236060.64 2268522.64 6947.00 23.70 256.80 5174.05 963.995 3937.60W 0.80 4053.85 236023.66 2268514.19 7044.00 24.80 256.70 5262.49 973.125 3976.37W 1.13 4093.69 235984.70 2268505.89 7139.00 25.20 256.10 5348.59 982.565 4015.40W 0.50 4133.84 235945.49 2268497.28 7235.00 24.40 254.70 5435.74 992.705 4054.36W 1.03 4174.10 235906.31 2268487.98 7331. 00 25.50 255.20 5522.78 1003.215 4093.47W 1.17 4214.58 235866.99 2268478.31 7427.00 24.90 255.80 5609.64 1013.455 4133.04W 0.68 4255.45 235827.21 2268468.92 7523.00 24.00 255.50 5697.03 1023.305 4171. 54W 0.95 4295.18 235788.51 2268459.90 7619.00 24.60 253.90 5784.52 1033.725 4209.64W 0.93 4334.66 235750.20 2268450.29 7715.00 26.10 255.30 5871.28 1044.635 4249.26W 1. 68 4375.74 235710.35 2268440.24 7809.00 25.30 254.20 5955.98 1055.345 4288.59W 0.99 4416.48 235670.80 2268430.37 7850.00 25.10 254.70 5993.08 1060.025 4305.41W 0.71 4433.93 235653.89 2268426.05 7910.00 25.10 254.70 6047.41 1066.745 4329.96W 0.00 4459.37 235629.20 2268419.86 ,/ All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level). Bottom hole distance is 4459.42 on azimuth 256.16 degrees from wellhead. Vertical section is from wellhead on azimuth 256.45 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ , e MARATHON Oil Company Falls Creek Unit fl,FC-4 Falls Creek Field,Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 7910.00 6047.41 Top MD Top TVD Rectangular Coords. e SURVEY LI5TING Page 3 Your ref MWD <0-7910> Last revised: 5-Feb-2004 Comment Comments in wellpath -------------------- -------------------- 1066.745 4329.96W Projection to TD Casing positions in string 'A' Rectangular Coords. ------------------------------ ------------------------------ Bot MD Bot TVD Rectangular Coords. ----------------------------------------------------------------------------------------------------------- Casing 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Target name O.OON O.OON O.OON O.OON O.OOE O.OOE O.OOE O.OOE 102.00 1840.00 4888.00 7910.00 102.00 1549.86 3302.28 6047.41 0.37N 174.095 744.755 1066.74S Geographic Location Targets associated with this wellpath ------------------------------------- ------------------------------------- T.V.D. 0.34E 773.17W 3108.53W 4329.96W 1072.625 758.085 Rectangular Coordinates 4331.03W 3144.39W 20 13 3/8" Casing 9 5/8" Casing 3 1/2" Casing Revised ----------------------------------------------------------------------------------------------------------- ll-Dec-2003 ll-Dec-2003 FC-4 TD Tgt 10-Dec-0 235628.000,2268414.000,999.00 FC-4 Beluga B2 Tgt 1 236821.080,2268703.050,999.00 5850.00 3375.00 t e e 1/9/2004 101 (ft) 1/10/2004 101 (ft) 1/11/2004 101 (ft) 1/12/2004 101 (ft) 1/13/2004 101 (ft) 1/14/2004 101 (ft) 1/15/2004 101 (ft) 1/16/2004 101 (ft) 1/17/2004 101 (ft) 1/18/2004 101 (ft) 1/1912004 101 (ft) 1/2012004 128 (ft) 1/2112004 730 (ft) 1/22/2004 1,412(ft) 1/23/2004 1,860 (ft) 1/2412004 1,860 (ft) 1/25/2004 1,860 (ft) 1/26/2004 1,860 (ft) 1/27/2004 2,250 (ft) 1/28/2004 3,325 (ft) RID rig. RID rig. RID rig and prep for move. RID rig and move non-permit loads. Move rig. RlU rig. RlU rig. RlU rig. RlU rig. RlU rig. Install starting head. NIU diverter and test. Prep to P/U DP. P/U DP. P/U DP. P/U BHA. Spud well @ 30:00hrs 01/20/2004. Drill 27' new hole to 128'. P/U MWD tools. Drill F/128' to 200'. Repair rig. Drill F/200' to 730'. Drill Fn30' to 1016'. Circ. clean. Wiper trip to CSG shoe. RIH. Drill F/1016' to 1412'. Drill F/1412' to 1860'. Circ. clean. POOH. Service rig. RIH. RIH. Circ. clean. POOH. RlU and run 133/8" CSG. Run 4" innerstring and circ CSG. Cement surface CSG. WOC. Cut 13 3/8" CSG. N/D diverter. NIU BOPE. N/U BOP. Test BOPE. Test CSG. Rig repair. P/U DP. RIH. Drill cement and shoe. Drill F/1860' to 1880'. Perform LOT. Drill F/1880' to 2250'. Drill F/2250' to 2895'. Circ. clean. Wiper trip to CSG shoe. RIH. Drill F/2895' to 3325'. PrinI8d: 5/1212004 1:41:59 PM e e 1/29/2004 4,138 (ft) 1/30/2004 4,900 (ft) 1/31/2004 4,900 (ft) 2/1/2004 4,900 (ft) 2/2/2004 5,288 (ft) 213/2004 6,439 (ft) 2/4/2004 7,583 (ft) 2/512004 7,910 (ft) 2/6/2004 7,910 (ft) Drilled f/3325' to 3947'. CBU. Wiper trip to shoe. Drilled f/3947' to 4138'. Drillf/4138't04900'. CBU. Wiper trip to 3598'. TIH. CBU. POOH, SLM. RlU & run 9-5/8" casing. Ran & cemented 9-518" casing. Install & test pack-off. Test BOPE. Prep to P/U DP. P/U DP. POOH. Test casing. P/U BHA, TIH. Drill shoe track & new formation to 4920'. LOT to 17.2 ppg EMW. Displace to new mud. Drill ahead f/4920' to 5288'. Drill f/5288' to 5957'. CBU. Pull to shoe. Slip & cut drilling line. Rig repair. TIH. Drill f/5957' to 6439'. Work on pumps. Drill f/6439' to 6913'. CBU. WT. Drill f/6913' to 7583'. Drill f/7583' to 7910'. CBU. WT. C & C for open hole logs. Pull to shoe. CBU. FPOOH. LD BHA. RlU loggers. Run open hole logs. RID loggers. Release rig to completion @ 16:30 hrs 2/512004. Printed: 5/12/2004 1:41:59 PM · e e 2/6/2004 7,910 (ft) 217/2004 7,910 (ft) 2/8/2004 7,910 (ft) 219/2004 7,910 (ft) 2/1012004 7,910 (ft) 2/11/2004 7,910 (ft) TIH. CBU. Pull to shoe. WOO. WOO. TIH. CBU. Pull to shoe. POOH, LOOP. LOOP. RlU to run 3-1/2" EXCAPE completion. Run modules 1 - 9. Continue running 3-1/2" completion casing. Run 3-1/2" EXCAPE completion casing. Circulate casing. Run correlation log. Put casing on depth. Cement casing. WOC. WOC. Lift BOP. Set slips. RIO BOP. Install/test packoff. Install/test production tree. ROMO. ROMO drilling equipment. Rig released @ 12:00 hrs, 2/10/2004. Printed: 5/1212004 1:42:29 PM e e 3/26/2004 7,910 (ft) Completed rigging up all frac equipment and lines. Perforated module one perfs. Pressure tested coil tubing lines and flowback lines to 4500 psi. Shut down for night. 3/26/2004 7,910 (ft) Complete rigging up all frac eqp and lines. Perforated module one perfs. Pressure tested coil tbg lines and flowback to 4500 psi. shut down for night. " 3/27/2004 7,910 (ft) Fracture treated 9 excape modules. RD frac equipment. RU coil tubing. RIH with coil tubing, Break flappers for excape modules 6,5,4,3, and 2. Attempt to locate flappers for excape modules 9,8,and 7 with out success. Preparing to POOH and jet well in 3/28/2004 7,910 (ft) POOH with CT to 1500'. Jetted well in from 1500'to 3000' with N2. POOH with CT and monitor well. Well loading up. RIH with CT and jet well in down to 5000'. POOH with CT and monitor flow. 3/29/2004 7,910 (ft) Flow well to test separator. Put well in sales at Midnight 0000 hrs 3-29-2004. Conitnued flowing and cleaning up well Printed: 5112/2004 1 :42:44 PM SUPERVISOR Gene Anderson FIELD NAME WilDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS RID ri . OPERATION COMMENTS RID rig. 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE MOC WI NRI 9072831315 COUNTY/OTHER DX0309624CAPDRl I CAlLY WF' I ,..,..~... . ...... r.""=.T Printed: 4/8/2004 9:40:32 AM SUPERVISOR Gene Anderson FIELD NAME WilDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENTSTATUS/MTS RID ri . OPERATION COMMENTS RID rig. 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE MOC WI NRI 9072831315 COUNTY/OTHER DX0309624CAPDRl _.-,--,- ,n.!.IIVU....·· - 06:00 09:00 3.00 101 101 AF RDMO RIG RID #1mud pump, RID pits, RID tarps and handrails for rig floor. 09:00 11:00 2.00 101 101 AF RDMO RIG Secure service loop in derrick. RID #2 mud pump. 11:00 12:00 1.00 101 101 AF RDMO RIG RID boom line, RID man rider, fold roof panels up, Prep rig floor and derrick for laying down. 12:00 14:00 2.00 101 101 AF RDMO RIG Prep derrick to UD. UD handrails on pits. Prep pits to move. RID steam and water lines on pits. 14:00 18:00 4.00 101 101 AF RDMO RIG UD derrick. Hang blocks. Move pits and connex. 18:00 20:00 2.00 101 101 AF RDMO RIG UD A-legs. RID steam and water on ODS sub. 20:00 00:00 4.00 101 101 AF RDMO RIG Fold up board. Chain up boom pole. Roll and tie tugger lines up. Unstring blocks. Spool drilling line. Prep motor and drawworks to move. 00:00 06:00 6.00 101 101 AF RDMO RIG Secure cables in derrick. Scope in derrick climber post. Steam clean rig. Demob sub. Prep drawworks to be moved. 3,060 Printed: 4/8/2004 9:40:36 AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRE~T STATUS / MTS Pre ri for move. OPERATION COMMENTS RID rig and prep for move. 16.5 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 101 AUTH MD 7,993 MOC WI NRI ....1 " WFJ I. ,.._r-_ 9072831315 COUNTY/OTHER LEAKOFF 06:00 12:00 6.00 101 101 AF RDMO RIG Blow down boiler and steam lines. RID steam hoses and air lines. Pull elec. wires. Prep pump room and boiler room for move. Lay down derrick. 12:00 00:00 12.00 101 101 AF RDMO RIG Unpin crown section and load on trailer. Unpin board section and load on trailer. Roll up service loops, hyd hoses, and electric lines on trailer and tie off. Roll goose neck up on standpipe. Tie up bridal lines. Load out boiler, MP#1 and MP#2. Fold grasshopper in place on SCR house. Load out Can-rig top drive SCR and generator. Install ramp and remove drawworks from rig floor. Fold up landing on doghouse and lower into water tank. Load out water tank. Install guards on eaton brake. attempt to remove pins on camp landing gear. Not successful. 00:00 06:00 6.00 101 101 AF RDMO RIG Prep derrick for move. Rigged down "A" leg saddles. RID rig floor extensions. Transfer fluid from boiler tank to portable tank. Prep pits for move. Roll up kelly hose. 20.000 3,060 Printed: 4/8/2004 9:40:39 AM SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS Waitin on da Ii hI. OPERATION COMMENTS RID and move non-permit loads. 16.5 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE AUTH MD 7,993 Mce WI fliRt --., I ',.,.r 9072831315 COUNTYIOTHER LEAKOFF REGULATORY INSP? N 06:00 12:00 6.00 101 101 AF RDMO RIG Pick up and load mats and pipe rack s on trailers. Load PPE cabinets on trailer. Install ground strap on portable fuel tank. Paint new tool racks. Hang fire curtain in conex for welder. 12:00 00:00 12.00 101 101 AF RDMO RIG Move non-permit loads to Go and Abalone pads to stage for Falls Creek. Prep permit loads for move. 00:00 06:00 6.00 101 101 AF RDMO WAIT Wait on daylight to start rig move. LAST BOP TEST: 20.000 LAST CASING TEST: (psi) @ (ppg) NEXT BOP TEST: 3,060 Printed: 4/8/2004 9:40:41 AM WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Wait for da Ii ht. OPERATION COMMENTS Move rig. 16.5 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 9072831315 COUNTY/OTHER AUTH MD 7,993 MOC WI NRI 'I ~t"'!>~- ,.' -. - LEAKOFF 06:00 12:00 6.00 101 101 AF RDMO RIG Secure loads on trucks. Remove centrifudge and feed pump from pits. Load trailers. Prep change room conex and generator skid. Transfer fuel. from suport camp tank. Load out oil drums. 12:00 20:30 8.50 101 101 AF MIRU RIG Move rig to Falls Creek pad. Remove well house from Falls Creek#3. Levi and prep location. Lay felt and liner. 20:30 00:00 3.50 101 101 AF MIRU RIG Sett matting boards. 00:00 06:00 6.00 101 101 AF MIRU WAIT Wait for daylight. LAST BOP TEST: LAST CASING TEST: 20.000 (psi) @ (ppg) NEXT BOP TEST: 3,060 Printed: 4/8/2004 9:40:43 AM FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS RIU ri . OPERATION COMMENTS RIU rig. 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE MOC WI NRJ 9072831315 COUNTY/OTHER _·1~" W!;i I cr . LEAKOFF 06:00 08:00 2.00 08:00 00:00 16.00 101 101 101 AF 101 AF MIRU MIRU WAIT RIG Wait for daylight. Set substructure. Make allowances for interference with Falls Creek#3 well. Assemble derrick sections. Set mud pump house. String up derrick lines. Pull back tugger lines. Tie off service loop. Install torque arrest beam in derrick. Prep derrick. Hook up lines in sub base and pump room. 00:00 06:00 6.00 101 101 AF MIRU RIG Printed: 4/8/2004 9:40:44 AM FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS RIUri . OPERATION COMMENTS RIU rig. 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE MOC WI NRI 9072831315 COUNTY/OTHER LEAKOFF 06:00 12:00 6.00 101 101 AF MIRU RIG 12:00 00:00 12.00 101 101 AF MIRU RIG Spot generator shed and hook up lines. Move matting boards and roll up herculite to make room for trucks to pass. Put up hand rails on rig floor. Change out tie down wires and install turn buckles on drillers side of sub. Spot camp loads. Set derrick on stand. Pin and raise a-legs. Set landing on camp. Spread herculite and set matting boards for pits. Set suction pit. Shim under back of pits to compensate for location. Hook up pop off lines. Prep lines to hook up shaker pit. Set shaker pit. Spot pits. Hook up lines in pits. String up drill line. Work on derrick lines and crown lights. Hook up water lines. 00:00 06:00 6.00 101 101 AF MIRU RIG LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 20.000 Printed: 4/8/2004 9:40:45 AM RIG PHONE 24 HR PROG TMD 101 AUTH MD 7,993 MOCWI WBS FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS RIU ri . OPERATION COMMENTS RIU rig. 16.5 RIG NAME & NO. NABORS DRILLING 129 NRI .,.~. . ---¡ 9072831315 COUNTY/OTHER LEAK OFF 06:00 12:00 6.00 101 101 AF MIRU RIG Work on walkways and general house keeping. Hang tarps in pits. Hook up glycol lines. Attend prespud meeting. 12:00 13:00 1.00 101 101 AF MIRU RIG Prespud meeting. 13:00 00:00 11.00 101 101 AF MIRU RIG Set boiler house. Set Can-rig SCR and generator. Set connex. Complete welding work on doghouse landing. Take on rig water. Circulate around rig. Fill boiler. Hook up steam lines. Circ. steam around rig. Trouble shoot and repair derrick lights. Load out truck swap loaders. Put up crown lights. Hang boom pole. Hook up board hanging line. Turn goose neck. Hook up kelly hose. Raise derrick. Hook up tuggers. Untie lines in derrick. Start putting up windwalls. 00:00 06:00 6.00 101 101 AF MIRU RIG Put up tarps on rig floor and fold down roof panels. RIU man rider and boom line. Unbridle blocks and hang bridle line in derrick. LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 3,060 20.000 (psi) @ (ppg) 133.00 Printed: 4/8/2004 9:40:46 AM WELL NAME FAllS CREEK 4 SUPERVISOR Rowland Lawson F!ELD NAME WilDCAT-FOR UNNAMED FIELD STATEJPROV Alaska CURRENT STATUS / MTS RlUri OPERATION COMMENTS RlU rig. 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE MOC W! NRI 9072831315 COUNTY/OTHER ._. ... ...-.. f"'O--- LEAKOFF 06:00 12:00 6.00 101 101 AF MIRU RIG RlU pits and fill w/water. Assemble landings and walkways for pits. Thaw out celler. RlU standpipe manifold. 12:00 00:00 12.00 101 101 AF MIRU RIG Untie and position in derrick service loop and hydraulic loop for top drive. Org. rig floor. W/O Peak truck(broken down). Set Epoch mud logging shack. Set Baker MWD shack. Set top drive trailer. P/U top drive. Pin in hanging lines. RID lifting assembly. Pin blocks to top drive. Attach TD to torque rail. Connect inside Hyd loop. Get heat on electrical loop. RlU kelly hose goose neck on top drive. RID hose from water well. Move Epoch and crane. RlU hose to water well. Attempt to set centrifudge on pits. Set dwon centrifudge for fabrication work. Assist crew to set up Nabors satcom. 00:00 06:00 6.00 101 101 AF MIRU RIG Install kelly hose and safety cable. Move service loop for top drive to other side of derrick. RlU degasser. Complete RJU of pits and begin to fill w/water. Build berm around matting boards Install heater by standpipe manifold. 20.000 3,060 Printed: 4/8/2004 9:40:47 AM SUPERVISOR Rowland Lawson F!ELD NAME 24 HR PROG TMD 16.5 101 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE MOC WI NRI 9072831315 COUNTY/OTHER . t":IIM W!=! I r.:n~T lEAKOFF 06:00 12:00 6.00 101 101 AF MIRU RIG Move traveling tools to rig floor. Hang tongs. lower derrick board. Work on pumps. ConI. RIU pits. Gather parts for N/U diverter. Complete hooking up boiler blow down. RIU washer dryer. Hook up pop off lines to pumps. Unload catwalk. 2 trailer loads of mud. 2 trailer loads rig parts. Run Can rig generator. Raise and set grasshopper. Pull wires up A-leg to control box for top drive. Prep for electrician. Start to mix mud. Assist electrician w/wiring top drive. Crane up and set centrifudge on pits. Spot and set cuttings tank. BOP Accepted rig @ OO:OOhrs 1/18/2004. 12:00 13:00 1.00 101 101 AF MIRU RIG 13:00 15:00 2.00 101 101 AF MIRU RIG 15:00 22:00 7.00 101 101 AF MIRU RIG 22:00 06:00 8.00 101 101 TA DRlSUR NUND Attempt to install 20 1/8" slip on starting head on 20" conductor. Had problems to get head all the way down. Stacked weight of diverter bag on head. Could not get slips to properly sel. Remove starting head. LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 20.000 133.00 3,060 Printed: 4/8/2004 9:40:49 AM ~', . - WELL NAME KB GL 24 HR PROG TMD TVD DFS DOL RPT# DATE FALLS CREEK 4 16.5 245.00 101 101 0 6 11 19-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I ~. ~"..~~ _".,._ Rowland Lawson NABORS DRILLING 129 7,993 DX0309624CAPDRL FIELD NAME R!G PHONE MOCWI NRI I nAil v WI'" ,.n..T 11"11.. 'AIel I ,,^r>"P I WILDCAT-FOR UNNAMED FIELD 9072831315 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 20.000 (in) @ 101 (ft) 13.375 (in) (á) 1,838 (ft) CURRENT STATUS / MTS 24 HR FORECAST P/U DP. P/U DP. Spud well. Drill ahead. OPERATION COMMENTS N/U diverter and test. Prep to P/U DP. P/U DP. ~;~ ~, 'it, ~ bÌlIr',~ .. -¡_iii, illt\iiœ_':I1'111UbJKZ'JIII1';, MANHRS WORKED I ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT I REGULATORY INSP? LAST RIG INSPECTION 326.00 None 1/18/2004 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: General rig safety. 06:00 08:30 2.50 101 101 TA DRLSUR NUND BOP Remove and dress 20 1/8" slip on starting head(found ice behind o-ring seals). 08:30 09:00 0.50 101 101 TA DRLSUR NUND BOP Install 20 1/8" slip on starting head. Test to 600psi/5min. 09:00 12:00 3.00 101 101 TA DRLSUR NUND BOP N/U 20" hydrill diverter and 16" diverter line. While N/U set cuttting tank, hook up troughs in mud pits, set diesel tank for Directional drillers/Mud engineers camp building. 12:00 15:00 3.00 101 101 AF DRLSUR NUND Cont. N/U diverter and hook up flow line. 15:00 17:30 2.50 101 101 AF DRLSUR RIG Connect hydraulics to top drive. Set catwalk. Install bales. Connect water and fuel to Directional drillers/Mud engineers camp building. 17:30 18:00 0.50 101 101 AF DRLSUR TEST Function test Diverter. 18:00 20:00 2.00 101 101 AF DRLSUR RIG Install belly board. Test split bushings fit into rotary. 20:00 23:00 3.00 101 101 AF DRLSUR RIG Install actuator for IBOP on top drive. 23:00 00:00 1.00 101 101 AF DRLSUR TRIP Prep to P/U DP. 00:00 02:30 2.50 101 101 AF DRLSUR TRIP Attempt to adjust kelly hose position for P/U DP(kelly hose interfering with belly board). 02:30 03:00 0.50 101 101 AF DRLSUR TRIP RIU to P/U DP. Hang anti-fall devices from belly board. 03:00 04:00 1.00 101 101 AF DRLSUR TRIP P/U DIP. Could not stand back pipe because kelly hose interfered with belly board. 04:00 05:00 1.00 101 101 AF DRLSUR TRIP UD kelly hose. Add weight to weight bucket for driller side tongs. 05:00 06:00 1.00 101 101 AF DRLSUR TRIP P/U DP. COMMENTS Lou Grimaldi (AOGCC) present for Diverter test. All gas alarms calibrated and tested by PSI company. ~ Nabors Alaska Drilling 17 204.00 Baker Hughes Inteq 2 48.00 Marathon 1 24.00 M-I Drilling Fluids 1 24.00 Epoch Well Services 2 24.00 S&R Enterprises 2 2.00 Printed: 4/8/2004 9:40:51 AM WELL NAME FALLS CREEK 4 LAST BOP TEST: 20.000 (psi) @ (ppg) 3,060 Printed: 4/8/2004 9:40:51 AM · ....... » ..\\ WELL NAME KB GL 24 HR PROG TMD TVD DFS DOL RPT# DATE FALLS CREEK 4 16.5 245.00 27.0 128 128 1 7 12 20-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS r.O!:T Rowland Lawson NABORS DRILLING 129 7,993 DX0309624CAPDRL FIELD NAME R!G PHONE MOCWI NRI I DAII V WFI '''''.T !rl!UwS:11 t""t'\C!:T WILDCAT-FOR UNNAMED FIELD 9072831315 ST A TElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF- Alaska 20.000 (in) (cù 101 (ft) 13.375 (in) (cù 1,838 (ft) CURRENT STATUS / MTS 24 HR FORECAST B/U MWD tools. Prep to drill ahead (cù 128'. Drill ahead. OPERATION COMMENTS P/U DP. P/U BHA. Spud well @ 30:00hrs 01/20/2004. Drill 27' new hole to 128'. MANHRS WORKED I ACCIDENT TYPE LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I REGULATORY INSP? LAST RIG INSPECTION 343.00 None 1/19/2004 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: General rig safety. 06:00 10:30 4.50 101 101 AF DRLSUR TRIP P/U 4" DP(total 66jnts) and 5" HWDP(total 23jnts) and jars(DP not torqued to spec. torque). 10:30 12:00 1.50 101 101 AF DRLSUR EQUIP RIU to P/U HWDP. CIO elevators. RIU torque gauges, snub line, adjust wt. on tong counter weights. 12:00 13:30 1.50 101 101 AF DRLSUR TRIP Adjust weight on tongs. Remove belly board. RIU spinning chain for HWDP. 13:30 16:00 2.50 101 101 AF DRLSUR TRIP P/U 23jnts 5" HWDP and Jars. 16:00 18:00 2.00 101 101 TA DRLSUR EQUIP SOTH Set centrifudge cuttings tank. Trouble shoot air actuated IBOP valve. Could not get air actuated valve to work. M/U HT -40 saver sub. 18:00 21:30 3.50 101 101 TA DRLSUR EQUIP SOTH Hook up kelly hose. Change angle of top drive. Loosen clamp on standpipe and adjust goose neck. 21:30 22:00 0.50 101 101 TA DRLSUR EQUIP SOTH Attempt to use new split bushings. Bushings stuck in rotary. Remove bushings. 22:00 22:30 0.50 101 101 TA DRLSUR EQUIP SOTH Dress bushings with grinder to fit rotary. 22:30 00:30 2.00 101 101 AF DRLSUR TRIP P/U 16" bit. M/U 8" Motor. Split bushing sticking in rotary. 00:30 01:30 1.00 101 101 TA DRLSUR EQUIP SOTH Dress bushings with grinder to fit rotary. 01:30 02:00 0.50 101 101 AF DRLSUR TRIP Cont. P/U BHA. 02:00 02:30 0.50 101 101 AF DRLSUR TRIP RIH and tag @ 26'. 02:30 03:00 0.50 101 101 AF DRLSUR CIRC Cire. and check for leaks. 03:00 04:30 1.50 101 128 AF DRLSUR DRILL Drill out 20" conductor and 27' new hole to 128'(ART=.5hrs). (Spud well @ 03:00hrs 1/20/2004). 04:30 05:00 0.50 128 128 AF DRLSUR CIRC Cire. hole clean. Flow line plugged off CÎrc. clear. 05:00 06:00 1.00 128 128 AF DRLSUR TRIP Raek back stand of DP and P/U 153/4" stab and MWD tools. COMMENTS Spud well @ 03:00hrs 01/20/2004. - ~~ ~~Ê+ 215 10/58 30/35 12.2/ I 2.0/3.5 /97 /22.5 9.00/0.4 0.2/0.51~;~~:~ I I 30 Printed: 4/8/2004 9:40:52 AM Nabors Alaska Drilling Marathon Epoch Well Services Baker Hughes Inteq M-I Drilling Fluids 17 204.00 S&R Enterprises 1 24.00 PSI 2 20.00 Alaska Petroleum Contra 2 48.00 R&K Industrial 1 24.00 1 1 1 1 2.00 8.00 8.00 5.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 3,060 (Ot~FiDEi~TiAl Printed: 4/8/2004 9:40:52 AM WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin ahead 730'. OPERATION COMMENTS P/U MWD tools. Drill F/128' to 200'. 16.5 RIG NAME & NO. NABORS DRILLING 129 R!G PHONE 24 HR PROG TMD 602.0 730 AUTH MD 7,993 MOC WI NRI ""IIJI\A1~11 r-!"!:.~T 9072831315 COUNTY/OTHER LEAKOFF Repair rig. Drill F/200' to 730'. 10:00 13:00 3.00 13:00 13:30 0.50 13:30 06:00 16.50 200 200 200 200 TA 200 TA 730 AF DRLSUR RIG DRLSUR TRIP DRLSUR DRILL Load MWD tools. Scribe MWD. Drill F/128' to 200'(ART=..8hrs) Attempt to orient motor. Top drive break would not hold. to above CSG shoe. TOPS Repair brake system on top drive. TOPS RIH to 200'. Dir drill and survey F/200' to 730'(ART=1.56hrs AST=9.49hrs). AVG. CONN: MAX. CONN: 2 4 Printed: 4/8/2004 9:40:53 AM 20.000 Printed: 4/8/2004 9:40:53 AM R!G PHONE 24 HR PROG TMD 682.0 1,412 AUTH MD 7,993 MOCWI HR! OJ " .", WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson F!ELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Drillin ahead 1412'. OPERATION COMMENTS Drill F/730'to 1016'. Circ. clean. 16.5 RIG NAME & NO. NABORS DRILLING 129 9072831315 COUNTY/OTHER lEAKOFF oint. RIH. Drill F/1016' to 1412'. 06:00 12:00 6.00 730 1,016 AF DRLSUR DRILL Dir drill and survey F/730' to 1 016'(ART=1.08hrs AST=4.16hrs). 12:00 13:00 1.00 1,016 1,016 AF DRLSUR CIRC Circ clean(CBUX3). 13:00 14:30 1.50 1,016 1,016 AF DRLSUR TRIP POOH to 891. Pulled 20k over. W/R 910' to 631 '(attempt to POOH but still pulling 20K over). 14:30 15:00 0.50 1,016 1,016 AF DRLSUR CIRC Circ. hole clean@ 630'(large cuttings load across shakers). 15:00 16:00 1.00 1,016 1,016 AF DRLSUR TRIP W/R F/630' to 160'. 16:00 16:30 0.50 1,016 1,016 AF DRLSUR CIRC Circ. clean @ 160'(large cuttings load across shakers). 16:30 17:00 0.50 1,016 1,016 AF DRLSUR TRIP POOH to 63'. 17:00 18:00 1.00 1,016 1,016 AF DRLSUR TRIP RIH to 1016'(hole good, wash down last 30'). 18:00 06:00 12.00 1,016 1,412 AF DRLSUR DRILL Dir drill and survey F/1016' to 1412'(ART=1.8hrs AST=6.32hrs). Printed: 4/8/2004 9:40:55 AM Printed: 4/8/2004 9:40:55 AM FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATEJPROV Alaska CURRENT STATUS 1 MTS RIH 24 HR PROG TMD 16.5 448.0 1,860 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE Mce WI NRI 9072831315 COUNTY/OTHER LEAKOFF 06:00 23:00 17.00 1,412 1,860 AF DRLSUR DRILL Dir drill and survey F/1412' to 1860'(ART=.53hrs AST=11.19hrs). 23:00 02:00 3.00 1,860 1,860 AF DRLSUR CIRC Cire, clean(CBUX4, 625gpm, 120RPM). 02:00 04:30 2.50 1,860 1,860 AF DRLSUR TRIP POOH(SLM,hole in good condition). Clean stabs and bit. 04:30 05:30 1.00 1,860 1,860 AF DRLSUR RIG Service rig. Clean and organize rig floor. 05:30 06:00 0.50 1,860 1,860 AF DRLSUR TRIP RIH. AVG. CONN: MAX. CONN: 22 63 Printed: 4/8/2004 9:40:56 AM Printed: 4/8/2004 9:40:56 AM WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Circ. 13 3/8" CSG. OPERATION COMMENTS RIH. Circ. clean. POOH. 24 HR PROG TMD 16.5 1,860 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE MOC WI NRI 9072831315 COUNTY/OTHER DX0309624CAPDRL IDAIl.Ytlt!~'I.COST ,..- _.__"".",V LEAKOFF N/U BOPE. 1,860 AF 1,860 AF 1,860 AF 1,860 AF 1,860 AF 1,860 AF 1,860 AF 23:00 23:30 0.50 1,860 1,860 AF RIH to 1860'. No fill. Circ. clean(CBUX4, 600GPM, 120RPM). POOH(hole slick). B/O bit. UD motor and MWD. C/O bales. RlU to run CSG. PJSM. M/U and Bakerlok first 3 joint. Circ. CSG. Check floats. Run 133/8" 68PPF K-55 Butt CSG(totaI45jnts, Shoe @ 1840', FC@1798'). Set CSG in slips. RID spider elevators. RlU side door elevators. P/U CSG off of slips. RID slip bowl. RlU base plate. Lower elevators and rest on base plate. RID long bales and Weatherford CSG running tools. M/U stab-in stinger and RIH w/4" DP to float collar @ 1798'. Space out and M/U head pin. Circ. and cond mud for cement(245gpm, 260psi). 48,000 70,000 60,000 64,000 4,000/4,000 37.46 16" MX-1 Tri-Cone bit wI center jet, Mach 1C/1.4AKO/15 7/8"UBHS , 15.75" String WBS , MWD Tool, Alignasub/HOS , Cross Over, Heavy Weight Drill Pipe (4), Hydraulic Jar/Bumper/Sub Combo tool, Heavy Weight Drill Pipe (19), Cross Over Printed: 4/8/2004 9:40:59 AM M-I Drilling Fluids R&K Industrial Weatherford BJ Services LAST BOP TEST: LAST CASING TEST: 20.000 13.375 (psi) @ (ppg) (psi) @ (ppg) 101 1,840 18.730 12.415 NEXT BOP TEST: 101 1,549 3,060 3,450 133.00 68.00 K-55 K-55 Printed: 4/8/2004 9:40:59 AM 24 HR PROG TMD 16.5 1,860 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE MOC WI HR! 9072831315 COUNTY/OTHER SUPERVISOR Rowland Lawson FIELD NAME WilDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENTSTATUS/MTS N/U BOPE. OPERATION COMMENTS Cement surface CSG. wac. LEAKOFF ConI. to circ. CSG and condition mud for cementing. PJSM prior to cementing. Line up BJ. Prep pits for cement job. Pump 5bbls water ahead. Test BJ lines to 2000psi. Mix and pump 35bbls 8.4ppg Mud Clean ahead. Mix and pump 434sxs Type1 cement w/18%lW-6, 20%MPA-1, 1%SMS, .3%CD-32, 19hs FP-6l to yeild 195bbls 12ppg slurry. Had full retums and 44bbls cement to surface. CIP@11:00 hrs. 10:30 11:00 0.50 1,860 1,860 AF Release pressure on BJ lines. Check floats. Drop cement plug and pump away with 17bbls mud from rig. Sting out of float shoe and pump plug out of pipe. 11:00 12:00 1.00 1,860 1,860 AF Pull 5 stands DP. Blow down TD. Flush stack. Function Diverter. Flush flowline and clean floor. 12:00 12:30 0.50 1,860 1 ,860 AF Clean and organize rig floor. 12:30 13:30 1.00 1,860 1,860 AF POOH wI innerstring. 13:30 19:00 5.50 1,860 1,860 AF While WOC(total 8hrs): UD cement tools. Start cleaning pits. Clean pipe racks for welder to make bigger drains. Clean floor and stack. UD mouse hole. Pull flow line indicator, wash out flow line. Prep to RID diverter. Adjust kelly hose. RID beaver slide. Move catwalk. 19:00 20:00 1.00 1,860 1,860 AF N/D bell nipple. N/D diverter line. NID knife valve. Lift diverter bag. 20:00 22:30 2.50 1,860 1,860 AF Remove base plate and elevators. Rough cut 13 3/8" CSG and UD. RlU pick up slings. RID bell nipple, diverter bag, diverter spool. Pull 20" well head. 22:30 01:00 2.50 1,860 1,860 AF Cut 20" conductor. Final cut 13 3/8" CSG and dress. C/O mud pump liners to 6". 01:00 02:00 1.00 1,860 1,860 AF Install Vetco 13 3/8" 5000psi MB-196 Multibowl wellhead. Test seals to 1000psi/10min. 02:00 06:00 4.00 1,860 1,860 AF N/U 135/8" 5M S,Rd,A BOP stack. Printed: 4/8/2004 9:41 :03 AM Printed: 4/8/2004 9:41 :03 AM WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Re lace drawworks en ine starter. OPERATION COMMENTS N/U BOP. Test BOPE. Test CSG. 24 HR PROG TMD 16.5 1,860 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE MOC WI NRI 9072831315 COUNTY/OTHER DX0309624CAPDRL nAil VWCI I -- !-,.."._- ,-~ -¡ LEAKOFF While cont to N/U 135/8" 5M BOP, set catwalk, clean pits, take on water and mix mud. Hook up choke line to choke hous and gas buster. Run control lines. Hook up electrical and speaker box. Set beaver slide. Install lower TD valve. 16:00 18:30 2.50 1,860 1,860 AF BIO cement stinger sub from cement job and UD. M/U 4" test string. 18:30 21:30 3.00 1,860 1,860 AF Test all choke manifold valves, upper variable rams, upper and lower TD valves, floor valve, inside and outside kill line valves, HCR and manual choke line valves to 250/3000psi 5min. 21:30 23:30 2.00 1,860 1,860 TA SOTH Test IBOP valve, HCR valve, and annular. Test failed. Adjust annular pressure. Find Vetco annular valve leaking. 23:30 00:00 0.50 1,860 1,860 AF CSGSU TEST Bull plug valve and test Annular 250/3000psi 10min. 00:00 01:00 1.00 1,860 1,860 AF CSGSU TEST Perform Koomey test. BIO of test plug and pull test string. 01:00 01:30 0.50 1,860 1,860 TA CSGSU TEST SOTH C/O annular valve on wellhead. 01:30 02:00 0.50 1,860 1 ,860 AF CSGSU TEST Test blind rams. 02:00 02:30 0.50 1,860 1,860 AF CSGSU TEST Pull test plug and run wear bushing. 02:30 04:00 1.50 1,860 1,860 AF CSGSU TEST Test 13 3/8" CSG against blind rams 2000psi/30min. 04:00 04:30 0.50 1,860 1 ,860 AF CSGSU EQUIP RIU drip pan under rotary table. Prep rig floor to P/U DP. 04:30 06:00 1.50 1,860 1,860 TA CSGSU RIG SHST Replace drawworks engine starter. COMMENTS Lou Grimaldi AOGCC waved BOP test. New centrifudge would not run off of Canrig generator. Rented generator for new centrifudge. Printed: 4/8/2004 9:41 :05 AM LAST BOP TEST: 1/26/2004 LAST CASING TEST: NEXT BOP TEST: 2/2/2004 20.000 13.375 18.730 12.415 (psi) @ (ppg) (psi) @ (ppg) 133.00 68.00 K-55 K-55 3,060 3,450 101 1,840 101 1,549 Printed: 4/8/2004 9:41:05AM WELL NAME FALLS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME 24 HR PROG TMD 16.5 390.0 2,250 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE MOCWI NRI 907283 1315 COUNTY/OTHER LEAK OFF 18.90 1,860 TA 1,860 AF 1 ,860 AF 1,860 AF 1,860 AF 1,860 AF Replace starter on drawworks engine. P/U 4" DP(totaI45jnts). Rack back in derrick. P/U bit, motor and MWD. Scribe BHA. RIH w/HWDP. Test MWD. ConI. RIH P/U 4" DP(totaI30jnts). Tag cement@1790'. Drill float collar cement and shoe to 1840'. Clean old hole to 1860'. Drill F/1860' to 1880'(ART=.1 hrs). Circ. clean and displace well to new 9.0ppg flopro mud. RIU BJ to do LOT. PJSM. Peñorm LOT to 18.9PPG EMW(9.0ppg MW, 797PSI). Dir drill and survey F/1880' to 2250'(ART=2.59hrs AST=2.03hrs ). 19:30 20:00 0.50 20:00 21 :00 1.00 21:00 21:30 0.50 21 :30 22:30 1.00 22:30 06:00 7.50 1,860 1,880 1,880 1,880 1,880 1,880 AF 1,880 AF 1,880 AF 1,880 AF 2,250 AF Printed: 4/8/2004 9:41 :06 AM Nabors Alaska Drilling 17 195.00 R&K Industrial 2 24.00 Marathon 1 24.00 Swaco 1 12.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 1 8.00 Baker Hughes Inteq 2 48.00 BJ Services 2 16.00 M-I Drilling Fluids 1 24.00 Printed: 4/8/2004 9:41 :06 AM FAllS CREEK 4 SUPERVISOR Rowland Lawson FIELD NAME 24 HR PROG TMD 16.5 1,075.0 3,325 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 RIG PHONE Moe WI NRI 9072831315 COUNTY/OTHER -..-" WELL C" LEAKOFF 18.90 06:00 16:30 10.50 2,250 2,895 AF DRLlN1 DRill Dir drill and survey F/2250' to 2895'(ART=6.64hrs AST=.87hrs). 16:30 18:00 1.50 2,895 2,895 AF DRLlN1 CIRC Cire. clean(CBUX4). 18:00 20:30 2.50 2,895 2,895 AF DRLlN1 TRIP POOH tíght@2560'. W/R 2585' to 2508'. POOH. Tight @ 2485', W/R 2490'to 2413'. POOH 2413't02112. Tight@2112 W/R 2112' to 1915'. POOH 1915' to 1830'. 20:30 21:30 1.00 2,895 2,895 AF DRLlN1 RIG Tighten connection bar on top dive upper J box. Service TD. Adjust kelly hose. 21:30 22:30 1.00 2,895 2,895 AF DRLlN1 TRIP RIH. Wash last stand to bottom. 22:30 06:00 7.50 2,895 3,325 AF DRLlN1 DRill Dir drill and survey F/2895' to 3325'(ART=5.63hrs AST=Ohrs). Printed: 4/8/2004 9:41 :08 AM 2,267.0 64.10 256.20 1,747.88 1,170.51 -257.62 -1,141.94 0.30 2,839.0 64.50 257.20 1,997.40 1,685.10 -372.03 -1,643.68 0.57 2,361.0 63.70 256.90 1,789.24 1,254.93 -277.25 -1,224.04 0.79 2,935.0 64.30 256.80 2,038.88 1,771.67 -391.50 -1,728.04 0.43 2,458.0 62.40 256.70 1,833.20 1,341.39 -297.00 -1,308.22 1.35 3,031.0 64.30 257.60 2,080.51 1,858.16 -410.67 -1,812.39 0.75 2,552.0 64.00 257.20 1 ,875.58 1,425.28 -315.94 -1,389.95 1.77 3,127.0 63.80 258.30 2,122.52 1,944.45 -428.69 -1,896.81 0.84 2,649.0 65.50 257.80 1,916.96 1,513.00 -334.92 -1,475.60 1.64 3,223.0 63.40 257.50 2,165.20 2,030.41 -446.71 -1,980.89 0.85 2,745.0 64.90 257.60 1,957.23 1,600.12 -353.49 -1,560.75 0.65 18.90 Printed: 4/8/2004 9:41 :08 AM SUPERVISOR Gene Anderson FIELD NAME WilDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Drillin ahead. OPERATION COMMENTS Drilled f/3325' to 3947'. CBU. 24 HR PROG TMD 16.5 813.0 4,138 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE MOCW! NR! --------.. ·--"1T 9072831315 COUNTY/OTHER LEAKOFF 18.90 Drilled fl 3947' to 4138'. 06:00 16:30 10.50 3,325 3,947 AF DRLlN1 DRill Directional drill & survey f/3325' to 3947' MD. ART 5.73 hrs. AST 2.05 hrs. 16:30 18:30 2.00 3,947 3,947 AF DRLlN1 TRIP CBU x 3 for wiper trip. 18:30 22:30 4.00 3,947 3,947 AF DRLlN1 TRIP Wipe hole to 13-3/8" casing shoe. Pull 3 stds, backream 18 stds, pull last std to shoe. 22:30 23:00 0.50 3,947 3,947 AF DRLlN1 RIG SR, service TID, clean rig floor. 23:00 01:00 2.00 3,947 3,947 AF DRLlN1 TRIP TIH. Ream last std to btm for safety, no fill. 01:00 06:00 5.00 3,947 4,138 AF DRLlN1 DRill Directional drill & survey f/3947' to 4138' MD. ART 2.05 hrs. AST 1.16 hrs. Printed: 4/8/2004 9:41 :11 AM D 3,318.0 62.70 257.70 2,208.26 2,115.08 -464.90 -2,063.59 0.76 3,796.0 52.40 255.00 2,461.66 2,519.31 -558.36 -2,456.88 1.74 3,414.0 61.90 257.80 2,252.88 2,200.05 -482.93 -2,146.66 0.84 3,892.0 50.80 255.10 2,521.29 2,594.52 -577.77 -2,529.56 1.67 3,510.0 59.60 257.10 2,299.79 2,283.79 -501.12 -2,228.41 2.48 3,987.0 49.00 255.40 2,582.48 2,667.17 -596.28 -2,599.83 1.91 3,606.0 56.50 256.10 2,350.58 2,365.24 -519.99 -2,307.64 3.35 4,083.0 46.30 254.90 2,647.15 2,738.10 -614.45 -2,668.41 2.84 3,700.0 54.00 255.60 2,404.16 2,442.46 -538.86 -2,382.53 2.70 Nabors Alaska Drilling 19 252.00 R&K Industrial 1 37.00 Marathon 1 24.00 Swaco 2 18.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 1 8.00 Baker Hughes Inteq 2 48.00 Alaska Oil Sales 1 2.00 M-I Drilling Fluids 1 24.00 Wildflowers and Resin 2 6.00 Printed: 4/8/2004 9:41:11 AM 24 HR PROG TMD 16.5 762.0 4,900 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE MOC 1m NRI 9072831315 COUNTY/OTHER .----; LEAKOFF 18.90 06:00 23:30 17.50 4,138 4,900 AF DRLlN1 DRILL Directional drill & survey f/4138' to 4900' MD. ART 7.02 hrs. AST 5.59 hrs. 23:30 02:30 3.00 4,900 4,900 AF DRLlN1 TRIP CBU x 4 for wiper trip. 02:30 05:30 3.00 4,900 4,900 AF DRLlN1 TRIP Wiper trip. Wipe hole to 3598' MD. (Pull 3 stds free, backream 13 stds, pull 3 tight stds, pull 2 stds free). Blow down T/D. 05:30 06:00 0.50 4,900 4,900 AF DRLlN1 TRIP TIH. No fill. Hole slick. COMMENTS Rack, strap & drift 122 jts, 9-5/8", 40 ppf, L-80, BTC casing, OAL 5028.36'. AVG. CONN: MAX. CONN: units 45 328 Printed: 4/8/2004 9:41:13 AM Nabors Alaska Drilling Marathon Epoch Well Services Baker Hughes Inteq M-I Drilling Fluids 19 252.00 R&K Industrial 1 24.00 Swaco 4 48.00 Lynden Transport 2 48.00 BJ Services 1 24.00 Weaver Brothers (WBI) 1 1 1 2 1 15.00 18.00 1.00 2.00 2.00 LAST CASING TEST: 1/26/2004 NEXT BOP TEST: 2/2/2004 20.000 13.375 18.730 12.415 18.90 (psi) @ (ppg) 764 (psi) @ 9.40 (ppg) 101 1,840 101 1,549 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 9:41 :13 AM 24 HR PROG TMD 16.5 4,900 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE MOC WI NRI 9072831315 COUNTY/OTHER r!.I!I.···,~·· ---- LEAKOFF 18.90 06:00 08:00 2.00 4,900 4,900 AF DRLlN1 TRIP C & C mud for casing. CBU x 3.5. Shakers clean. 08:00 13:00 5.00 4,900 4,900 AF DRLlN1 TRIP Check for flow. POOH wet to 13-3/8" csg shoe. Pump dry job. FPOOH. SLM, no correction. 13:00 15:00 2.00 4,900 4,900 AF DRLlN1 TRIP Retrieve MWD probe. UD MWD, WBS, mud motor, bit. 15:00 16:00 1.00 4,900 4,900 AF CSGIN1 NUND Change top rams to 9-5/8". 16:00 18:30 2.50 4,900 4,900 AF CSGIN1 EQUIP UD elevators, short bales. Change out saver sub. Pull wear bushing. 18:30 19:30 1.00 4,900 4,900 AF CSGIN1 TEST RlU & shell test 9-5/8" rams housing to 250 psi low/2500 psi high. RID test eqpt. 19:30 21:30 2.00 4,900 4,900 AF CSGIN1 EQUIP RlU to run 9-5/8" casing. RlU fill-up tool. P/U long bales, elevators, spiderlslips, elevators, casing tongs, air hoses. PJSM. 21:30 22:30 1.00 4,900 4,900 AF CSGIN1 CSG Make dummy run wI casing hanger. 22:30 23:30 1.00 4,900 4,900 AF CSGIN1 CSG P/U shoe jt, 2nd joint, unable to pump through fill-up tool. 23:30 00:00 0.50 4,900 4,900 AF CSGIN1 CSG Thaw out fill-up tool, remove ice plugs. 00:00 04:30 4.50 4,900 4,900 AF CSGIN1 CSG PJSM. P/U float jt, Bakerlok btm 2 jts. Run 9-5/8" casing to 13-3/8" shoe. 44 its in hole. 04:30 05:00 0.50 4,900 4,900 AF CSGIN1 CSG Circulate @ shoe. 74 its remaining. 05:00 06:00 1.00 4,900 4,900 AF CSGIN1 CSG Continue running 9-5/8" casing. 88 its in hole, 60 its remaining. Printed: 4/8/2004 9:41:14 AM Nabors Alaska Drilling Marathon Epoch Well Services Baker Hughes Inteq M-I Drilling Fluids R&K Industrial Swaco 19 252.00 BJ Services 1 1.00 1 24.00 Weatherford 4 30.00 4 48.00 Weaver Brothers (WBI) 1 2.00 2 48.00 S&R Enterprises 1 1.00 1 24.00 Alaska Oil Sales 1 2.00 2 11.00 PSI Alarm Check 1 4.00 1 2.00 NEXT BOP TEST: GRADE K-55 K-55 2/2/2004 . .;BURSif'sl .. 3,060 3,450 133.00 68.00 Printed: 4/8/2004 9:41:14 AM SUPERVISOR Gene Anderson F!ELD NAME 24 HR PROG TMD 16.5 4,900 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHONE MOC \\'1 DX0309624CAPDRL NRI I CAll V Wl:t, ---- I WILDCAT-FOR UNNAMED FIELD 9072831315 STAT~PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pre are to P/U drill i e. OPERATION COMMENTS Ran & cemented 9-5/8" casing. Install & test pack-off. Test BOPE. Prep to P/U DP. ..c:AI\OFF , drill shoe, LOT, C/O mud. BOP PSI TEST 2/1/2004 10:30 12:00 1.50 4,900 4,900 AF CSGIN1 CIRC 12:00 14:00 2.00 4,900 4,900 AF CSGlN1 CEMT 14:00 15:00 1.00 4,900 4,900 AF CSGIN1 CSG 15:00 16:00 1.00 4,900 4,900 AF CSGIN1 NUND 16:00 17:00 1.00 4,900 4,900 AF CSGIN1 NUND 17:00 21:30 4.50 4,900 4,900 AF CSGlN1 EQUIP 21:30 23:00 1.50 4,900 4,900 AF CSGIN1 EQUIP 23:00 00:00 1.00 4,900 4,900 AF CSGIN1 TEST 00:00 04:30 4.50 4,900 4,900 AF CSGIN1 TEST Finish running 9-5/8" casing. Ran 118 jts, OAL 4896.76', 9-5/8", 40 ppf, L-80, BTC casing including float shoe, float collar, casin hanger & landing joint. Bottom of float shoe @ 4888.39' & top 0 float collar @ 4801.83' MD. M/U landing joint & casing hanger. Land casing on load shoulder wI 167 ,000 Ibs. Install XO & cementing head. RlU cementing hose. Circulate casing @ 8.5 bpm & 386 psi. Condition mud for cement job. PJSM. Cement 9-5/8" casing as follows: Pump 5 bbls water ahead. Test lines to 3000 psi. Drop btm plug. Mix & pump 27 bbls 10. ppg weighted spacer. Mix & pump 400 sx (150 bbls) lead cement + additives mixed @ 12.5 ppg, 2.10 cf/sk followed by 175 sx (50 bbls) tail cement + additives mixed @ 13.5 ppg, 1.84 cf/sk. Drop top plug. Chase plug wI 5 bbls water. Displace cement wI 359 bbls 9.8 ppg mud @ 8.5 bpm & 525 psi. Bump plug wI 1135 psi. CIP @ 14:05 hrs, 01/31/2004. Bleed pressure, floats held ok. Full circulation throughout cement job. RID cementers. UD landing joint. UD elevators, flush stack. Install & test secondary packoff to 5000 psi for 10 mins. Change upper rams to VBR's. Clean mud pits. Work on T/D. Change liners in mud pumps to 5-1/2". UD fill-up tool, install saver sub, change dies in T/D. Install short bales. RlU to test BOPE. Install test plug & test joint. Test BOPE. Test annular, pipe rams, HCR, choke & kill line valves, choke manifold valves 1 - 18, manual & hydraulic choke, upperllower kelly valves & inside BOP to 250 psi low/3000 psi high. Pull test joint, test blind rams to 250 psi low/3000 psi high. Test Koomey. Check trip tank, pit level indicators, flow Printed: 4/8/2004 9:41:16 AM indicator. RID test eqpt, blow down lines. Install guide on TID handler. RlU to P/U DP. COMMENTS BOPE test witnessed by Jeff Jones, AOGCC. Nabors Alaska Drilling 19 252.00 BJ Services 5 30.00 Marathon 1 24.00 Weatherford 4 24.00 Epoch Well Services 4 48.00 Alaska Oil Sales 1 1.00 Baker Hughes Inteq 2 48.00 PSI Gas Alarm Tester 1 6.00 M-I Drilling Fluids 1 24.00 Weaver Brothers (WBI) 1 1.00 R&K Industrial 6 55.00 AOGCC Test BOP 1 5.00 20.000 13.375 9.625 18.730 12.415 8.835 18.90 (psi) @ (ppg) 764 (psi) @ 9.40 (ppg) (psi) @ (ppg) 101 1,840 4,888 101 1,549 3,302 133.00 68.00 40.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 9:41:16AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson F!ELD NAME 16.5 24 HR PROG TMD 388.0 5,288 AUTH MD 7,993 MOC WI NRI DX0309624CAPDRL DI>.......··· -- I cn--r RIG NAME & NO. NABORS DRILLING 129 R!G PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin ahead. OPERATION COMMENTS P/U DP. POOH. Test casing. P/U BHA, TIH. Drill shoe track & new formation to 4920'. LOT to 17.2 ppg EMW. Displace to new mud. Drill ahead f/4920' to 5288'. 9072831315 COUNTY/OTHER LEAKOFF 17.20 06:00 11:00 5.00 4,900 4,900 AF CSGIN1 TRIP Install wear bushing. P/U 90 jts 4" HT40 DP. SLM. 11:00 12:30 1.50 4,900 4,900 AF CSGIN1 TRIP POOH. 12:30 14:00 1.50 4,900 4,900 AF CSGIN1 TRIP Clean rig floor. P/U PDC bit, mud motor, WBS, MWD. 14:00 15:00 1.00 4,900 4,900 AF CSGIN1 TEST RlU to test casing. Close annular preventer & test 9-5/8" casing to 2000 psi for 30 minutes, ok. RID, blow down lines. 15:00 17:00 2.00 4,900 4,900 AF CSGIN1 TRIP Install probe in MWD, TIH wI HWDP. Test MWD. 17:00 19:30 2.50 4,900 4,900 AF CSGIN1 TRIP TIH. 19:30 21:00 1.50 4,900 4,900 AF CSGIN1 DRILL Tag top cement plug @ 4797' MD. Drill plugs, float collar @ 4801', shoe track & float shoe @ 4888' MD. C/O to previous T @ 4900' MD. 21:00 21:30 0.50 4,900 4,920 AF CSGIN1 DRILL Drill fl 4900' to 4920' MD. ART 0.26 hrs. 21:30 22:00 0.50 4,920 4,920 AF CSGIN1 CIRC Circulate hole to 9.5 ppg MW inlout. 22:00 23:00 1.00 4,920 4,920 AF CSGIN1 TEST Pull to 4904' MD. RlU to test. Test lines to 2000 psi. Perform LOT to 17.2 ppg EMW, shoe depth 4888' MD/3302' TVD, MW 9.5 ppg, leak off pressure 1320 psi. Bleed pressure, RID. 23:00 00:00 1.00 4,920 4,920 AF DRLPR MUD Displace hole to new 9.0 ppg FLOPRO mud system. 00:00 06:00 6.00 4,920 5,288 AF DRLPR DRILL Directional drill & survey fl 4920' to 5288' MD. ART 3.20 hrs. AST 0.63 hrs. Printed: 4/8/2004 9:41:17 AM 20.000 13.375 9.625 18.730 12.415 8.835 18.90 17.20 (psi) @ (ppg) 764 (psi) @ 9.40 (ppg) 1,389 (psi) @ 9.10 (ppg) 101 1,840 4,888 101 1,549 3,302 133.00 68.00 40.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 9:41 :17 AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD 24 HR PROG TMD 16.5 1,151.0 6,439 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 R!G PHQNE Mac WI NR! 9072831315 COUNTY/OTHER r.111UI we. I ,.._~~ LEAKOFF 17.20 06:00 13:00 7.00 5,288 5,957 AF DRLPR DRILL Directional drill & survey fl 5288' to 5957' MD. AST 0.92 hrs. ART 4.78 hrs. 13:00 14:00 1.00 5,957 5,957 AF DRLPR TRIP CBU x 2 for WT. 14:00 15:30 1.50 5,957 5,957 AF DRLPR TRIP Wipe hole to 9-5/8" casing shoe. Hole slick first 8 stds, backream 2 stds, pump last std to shoe (T/D would not rotate). 15:30 18:00 2.50 5,957 5,957 AF DRLPR RIG Slip & cut 279' drilling line. Service rig. 18:00 20:30 2.50 5,957 5,957 TA DRLPR RIG TOPS Rig repair. Work on TID electrical control system. 20:30 21:00 0.50 5,957 5,957 AF DRLPR TRIP TlH, no fill. 21:00 03:00 6.00 5,957 6,407 AF DRLPR DRILL Directional drill & survey fl 5957' to 6407' MD. AST 0.98 hrs. ART 1.97 hrs. 03:00 04:00 1.00 6,407 6,407 TA DRLPR MUD FLDS Change liner gasket on #2 pump. 04:00 04:30 0.50 6,407 6,436 AF DRLPR DRILL Directional drill & survey fl 6407' to 6436' MD. ART 0.11 hrs. 04:30 05:00 0.50 6,436 6,436 TA DRLPR MUD FLDS Work on pumps. Tighten liner gasket on both pumps. 05:00 05:30 0.50 6,436 6,439 AF DRLPR DRILL Directional drill & survey f/6436' to 6439' MD. AST 0.11 hrs. 05:30 06:00 0.50 6,439 6,439 TA DRLPR MUD FLDS Work on pumps. Tighten liner gasket on #1 pump. Printed: 4/8/2004 9:41 :20 AM . I . . WELL NAME KB IGL 24 HR PROG TMD TVD lDFS DOL RPT# DATE FALLS CREEK 4 16.5 245.00 1,151.0 6,439 4,711 15 21 26 03-Feb-2004 ~~ 2 I GARDNER-DENVER I 9.000 I 5.500 105 I 279.92 I 2,250 I 559.84 I 46 380 . ., MUD GAS . I UNITS· I units AVG. CONN: I AVG. TRIP: AVG. BKGRD: 16 MAX. CONN: MAX. TRIP: 315 MAX. DRL: 1,649 5,323.0 24.40 254.30 3,698.36 3,376.31 -787.43 -3,283.21 0.62 5,897.0 24.60 253.00 4,218.65 3,618.64 -849.35 -3,517.55 0.69 5,419.0 25.50 256.60 3,785.40 3,416.79 -797.59 -3,322.40 1.53 5,992.0 24.10 253.10 4,305.20 3,657.74 -860.77 -3,555.02 0.53 5,514.0 25.30 255.40 3,871.22 3,457.54 -807.44 -3,361.94 0.58 6,088.0 24.90 252.80 4,392.56 3,697.48 -872.44 -3.593.08 0.84 5,609.0 25.10 255.70 3,957.18 3,497.98 -817.54 -3,401.11 0.25 6,184.0 25.00 253.40 4,479.60 3,737.90 -884.22 -3.631.82 0.28 5,705.0 24.60 255.40 4,044.29 3,538.32 -827.60 -3,440.17 0.54 6,280.0 24.70 254.20 4,566.71 3,778.20 -895.47 -3,670.56 0.47 5,801.0 24.90 254.40 4,131.47 3,578.50 -838.07 -3,478.98 0.54 6,376.0 24.20 255.50 4,654.10 3,817.92 -905.86 -3,708.91 0.77 Nabors Alaska Drilling 19 252.00 S&R Enterprises 2 2.00 Marathon 1 24.00 Alaska Oil Sales 1 1.00 Epoch Well Services 4 48.00 ABB Vetco Gray 1 1.00 Baker Hughes Inteq 2 48.00 Oilfield Hot Shot Service 1 1.00 M-I Drilling Fluids 1 24.00 Veco Alaska 1 1.00 Swaco 1 6.00 Carlile Transportation Sy 1 1.00 R&K Industrial 1 11.00 Wildflowers and Resin 2 6.00 Weaver Brothers (WBI) 1 1.00 . . . <.. . ". . CASING SUMMARY·, .. ,.';'.' ., ".. . LAST BOP TEST: 2/1/2004 LAST CASING TEST: 2/1/2004 NEXT BOP TEST: 2/8/2004 ,SI:ZE (in) 10 (in) SHOE TEST \iJ~~J I .' I MD (ft) TvD (ft ~ 20.000 18.730 (psi) @ (ppg) 101 101 133.00 K-55 3,060 13.375 12.415 18.90 764 (psi) @ 9.40 (ppg) 1,840 1,549 68.00 K-55 3,450 9.625 8.835 17.20 1,389 (psi) @ 9.10 (ppg) 4,888 3,302 40.00 L-80 5,750 Printed: 4/8/2004 9:41 :20 AM KB RIG PHONE 24 HR PROG TMD 1,144.0 7,583 AUTH MD 7,993 MOCW! TVD 5,752 WBS FALLS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME 16.5 RIG NAME & NO. NABORS DRILLING 129 --, NRI WILDCAT-FOR UNNAMED FIELD 9072831315 STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drillin ahead. OPERATION COMMENTS Drill f/6439' to 6913'. CBU. WT. Drill f/6913' to 7583'. LEAKOFF 17.20 06:00 06:30 0.50 6,439 6,439 TA DRLPR MUD FLDS Work on pumps. Tighten liner gasket on #1 pump. 06:30 14:00 7.50 6,439 6,913 AF DRLPR DRILL Directional drill & survey f/6439' to 6913' MD. AST 2.69 hrs. ART 2.62 hrs. 14:00 15:30 1.50 6,913 6,913 AF DRLPR TRIP CBU x 3 forWT. 15:30 16:30 1.00 6,913 6,913 AF DRLPR TRIP Wipe hole 11 stds to 5856', hole slick. 16:30 17:00 0.50 6,913 6,913 AF DRLPR TRIP TIH. Wash last std to bottom for safety, no fill. 17:00 21:30 4.50 6,913 7,104 AF DRLPR DRILL Directional drill & survey f/6913' to 7104' MD. AST 1.76 hrs. ART 0.81 hrs. 21:30 22:00 0.50 7,104 7,104 AF DRLPR WLCNTL BGG jumped f/250 units to 1689 units in 1 minute. Shut down pumps, check for flow. Well dead. Circulate gassy mud out of hole. 22:00 06:00 8.00 7,104 7,583 AF DRLPR DRILL Directional drill & survey fl 7104' to 7583' MD. AST 2.22 hrs. ART 2.38 hrs. Printed: 4/8/2004 9:41 :25 AM 6,470.0 24.40 256.90 4,739.77 3,856.60 -915.08 -3,746.48 0.65 7,044.0 24.80 256.70 5,262.49 4,093.69 -973.12 -3,976.37 1.13 6,566.0 24.70 255.40 4,827.10 3,896.48 -924.64 -3,785.20 0.72 7,139.0 25.20 256.10 5,348.59 4,133.84 -982.56 -4,015.40 0.50 6,661.0 25.00 255.70 4,913.30 3,936.40 -934.60 -3,823.86 0.34 7,235.0 24.40 254.70 5,435.74 4,174.10 -992.70 -4,054.36 1.03 6,757.0 24.50 255.30 5,000.48 3,976.58 -944.66 -3,862.77 0.55 7,331.0 25.50 255.20 5,522.78 4,214.58 -1,003.21 -4,093.47 1.17 6,853.0 23.90 255.00 5,088.04 4,015.93 -954.74 -3,900.81 0.64 7,427.0 24.90 255.80 5,609.64 4,255.45 -1,013.45 -4,133.04 0.68 6,947.0 23.70 256.80 5,174.05 4,053.85 -963.99 -3,937.60 0.80 7,523.0 24.00 255.50 5,697.03 4,295.18 -1,023.30 -4,171.54 0.95 Nabors Alaska Drilling Marathon Epoch Well Services Baker Hughes Inteq M-I Drilling Fluids LAST CASING TEST: 2/1/2004 NEXT BOP TEST: 2/8/2004 20.000 18.730 (psi) @ (ppg) 101 101 133.00 K-55 3,060 13.375 12.415 18.90 764 (psi) @ 9.40 (ppg) 1,840 1,549 68.00 K-55 3,450 9.625 8.835 17.20 1,389 (psi) @ 9.10 (ppg) 4,888 3,302 40.00 L-80 5,750 Printed: 4/8/2004 9:41 :25 AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS LD BHA. 16.5 RIG NAME & NO. NABORS DRILLING 129 24 HR PROG TMD 327.0 7,910 AUTH MD 7,993 MOCWI DX0309624CAPDRL RIG PHONE HR! 1'11..'.''''"1 --....... l 9072831315 COUNTY/OTHER LEAKOFF 17.20 06:00 12:30 6.50 7,583 7,910 AF DRLPR DRILL Directional drill & survey f/7583' to 7910' MD TD. ART 1.69 hrs AST 2.22 hrs. 12:30 14:30 2.00 7,910 7,910 AF DRLPR TRIP CBU x 3 forWT. 14:30 16:00 1.50 7,910 7,910 AF DRLPR TRIP Wipe hole 12 stds to 6913'. Backream std 9 off bottom. 16:00 16:30 0.50 7,910 7,910 AF DRLPR EQUIP Turn stand pipe to locate kelly hose in better position to trip. 16:30 17:00 0.50 7,910 7,910 AF DRLPR TRIP TIH. Wash last std to bottom for safety, no fill. 17:00 19:00 2.00 7,910 7,910 AF DRLPR TRIP Circulate & condition hole for open hole logs. CBU x 3. 19:00 00:30 5.50 7,910 7,910 AF DRLPR TRIP POOH for open hole logs. SLM. Pull wet to 9-5/8" shoe. 33 stds to shoe. Backream std 11, 13, 21-23, 25-27, 30-33. 00:30 01:30 1.00 7,910 7,910 AF DRLPR CIRC CBU. Mix & pump dry job. 01:30 04:30 3.00 7,910 7,910 AF DRLPR TRIP POOH to BHA, SLM, no correction. 04:30 06:00 1.50 7,910 7,910 AF DRLPR TRIP LD BHA. Retrieve MWD probe. LD MWD tool. LD WBS, mud motor, bit. COMMENTS Received 260 jts, 3-1/2", 9.3 ppf, L-80, Mod 8RD casing including 1 jt wI float shoe + pup & 1 jt wI float collar. 114,000 12,000/9,000 8-1/2" HTC HCM605 PDC Bit, 6-3/4" M1XL w/1.10 deg AKO, 8-3/8" NMWBS, 6-9/16" MWD, 6-3/4" HOS, XO, 5" 49.5 ppf HWDP (4), 6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 4 1/2" IF-P X HT -40-B Printed: 4/8/2004 9:41 :26 AM Nabors Alaska Drilling 19 252.00 R&K Industrial 2 15.00 Marathon 1 24.00 Weaver Brothers (WBI) 2 3.00 Epoch Well Services 4 48.00 S&R Enterprises 2 2.00 Baker Hughes Inteq 2 48.00 Epoch Well Services Install dish 2 8.00 M-I Drilling Fluids 1 24.00 Wildflowers and Resin 2 6.00 Swaco 1 6.00 20.000 13.375 9.625 18.730 12.415 8.835 18.90 17.20 (psi) @ (ppg) 764 (psi) @ 9.40 (ppg) 1,389 (psi) @ 9.10 (ppg) 101 1,840 4,888 101 1,549 3,302 133.00 68.00 40.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 9:41 :26 AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME 24 HR PROG TMD 16.5 7,910 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE Moe WI NRI 9072831315 COUNTY/OTHER LEAKOFF 17.20 16:30 hrs, 2/5/2004. 06:00 06:30 0.50 7,910 7,910 AF EV ALPR LOG Clean rig floor to RlU loggers. 06:30 09:30 3.00 7,910 7,910 AF EV ALPR LOG PJSM. RlU loggers, hang sheaves. M/U Quad Combo logging suite of tools. Load RA source. 09:30 15:30 6.00 7,910 7,910 AF EVALPR LOG Run Quad Combo logging suite fl 7906' to 4888' MD. Logger's WIL TD 7906' MD. 9-5/8" shoe WIL measurement 4888' MD. 15:30 16:30 1.00 7,910 7,910 AF EV ALPR LOG RID loggers. I 8-1/2" HTC HCM605 PDC Bit, 6-3/4" M1XL w/1.10 deg AKO, 8-3/8" NMWBS , 6-9/16" MWD, 6-3/4" HOS ,XO , 5" 49.5 ppf HWDP (4), 6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 4 1/2" IF-P X HT-40-B units Nabors Alaska Drilling Marathon Epoch Well Services 19 126.00 Epoch Well Services 1 12.00 Baker Hughes Inteq 2 12.00 M-I Drilling Fluids Consultant 10.00 12.00 12.00 Printed: 4/8/2004 9:41 :28 AM Weaver Brothers (WBI) Reeves Wireline Carlile Transportation Sy LAST BOP TEST: 2/1/2004 20.000 13.375 9.625 18.730 12.415 8.835 NEXT BOP TEST: 2/8/2004 18.90 17.20 (psi) @ (ppg) 764 (psi) @ 9.40 (ppg) 1,389 (psi) @ 9.10 (ppg) 3,060 3,450 5,750 101 1,840 4,888 101 1,549 3,302 133.00 68.00 40.00 K-55 K-55 L-80 Printed: 4/8/2004 9:41 :28 AM WELL NAME FAllS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME 16.5 RIG NAME & NO. NABORS DRilLING 129 24 HR PROG TMD 7,910 AUTH MD 7,993 MOCWI HRI R!G PHONE 9072831315 COUNTY/OTHER LEAK OFF 17.20 16:30 17:00 0.50 7,910 7,910 AF RCMP TRIP M/U 8-1/2" RR tricone bit, XO to HWDP. 17:00 20:00 3.00 7,910 7,910 AF RCMP TRIP TIH wI HWDP, 4" drill string to casing shoe. Break circulation. 20:00 22:00 2.00 7,910 7,910 AF RCMP TRIP FTIH to btm. Wash last std to btm for safety, no fill. Hole slick. 22:00 01:00 3.00 7,910 7,910 AF RCMP CIRC Circulate & condition hole for 3-1/2" EXCAPE completion. 01:00 04:00 3.00 7,910 7,910 AF RCMP TRIP Pull to shoe, hole slick. 04:00 04:30 0.50 7,910 7,910 AF RCMP CIRC CBU, shakers clean. 04:30 05:00 0.50 7,910 7,910 AF RCMP RIG Service rig, T/D. 05:00 06:00 1.00 7,910 7,910 AF RCMP WAIT WIO Expro EXCAPE personnel to run completion. Clean & organize floor & work areas. Work on #2 pump. AVG. CONN: MAX. CONN: 308 units 15 308 Printed: 4/8/2004 9:50:07 AM LAST BOP TEST: 2/1/2004 9.625 17.20 5,750 Printed: 4/8/2004 9:50:07 AM FAllS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME WilDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS POOH, LOOP. OPERATION COMMENTS WOO. TIH. CBU. Pull to shoe. POOH, lOOP. 16.5 RIG NAME & NO. NABORS DRilLING 129 24 HR PROG TMD 7,910 AUTH MD 7,993 MOCW! NRI , CUM "A JELL ceST RIG PHONE 9072831315 COUNTY/OTHER LEAKOFF 17.20 06:00 13:00 7.00 7,910 7,910 AF RCMP WAIT WIO Expro personnel to run EXCAPE completion. WIO partner approval of module setting depths. Clean mud pits & cellar. Trouble shoot SCR #1. 13:00 15:00 2.00 7,910 7,910 AF RCMP TRIP TIH. Wash last std to btm for safety, no fill. Hole slick. 15:00 16:30 1.50 7,910 7,910 AF RCMP TRIP CBU x 2. Shakers clean. 16:30 18:30 2.00 7,910 7,910 AF RCMP TRIP Pull 35 stds to 9-5/8" casing shoe. Hole slick. 18:30 19:00 0.50 7,910 7,910 AF RCMP TRIP Clean floor. RIU to UD DP. Mix & pump dry job. 19:00 00:00 5.00 7,910 7,910 AF RCMP TRIP POOH, lD 107 jts DP. 00:00 00:30 0.50 7,910 7,910 AF RCMP TRIP TIH 35 stds. 00:30 01:30 1.00 7,910 7,910 AF RCMP TRIP UD 8 jts, pipe came wet. 01:30 02:00 0.50 7,910 7,910 AF RCMP TRIP Mix & pump dry job. 02:00 06:00 4.00 7,910 7,910 AF RCMP TRIP POOH, UD 80 jts DP. 30 jts left to top of HWDP. Printed: 4/8/2004 9:50:10 AM Nabors Alaska Drilling Marathon M-I Drilling Fluids Epoch Well Services R&K Industrial 19 252.00 Expro 6 12.00 1 24.00 Wildflowers and Resin 1 1.00 1 24.00 BJ Services 1 2.00 2 24.00 Lynden Transport 1 1.00 2 24.00 Peak Load DP. 1 6.00 LAST BOP TEST: 2/1/2004 LAST CASING TEST: 2/112004 NEXT BOP TEST: 2/8/2004 9.625 17.20 5,750 CONFIDENTIAL Printed: 4/8/2004 9:50:10 AM 24 HR PROG TMD FAllS CREEK 4 16.5 7,910 6,051 SUPERVISOR RIG NAME & NO. AUTH MD WBS Gene Anderson NABORS DRilLING 129 7,993 FIELD NAME RIG PHONE MOC WI NRI WilDCAT-FOR UNNAMED FIELD 9072831315 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Run 3-1/2" EXCAPE com letion. OPERATION COMMENTS lDDP. RIU to run 3"1/2" EXCAPE completion. r:IJM Wl'll COST LEAKOFF 17.20 06:00 07:30 1.50 7,910 7,910 AF RCMP TRIP POOH UD 30 jts DP to top of HWDP. 07:30 09:30 2.00 7,910 7,910 AF RCMP TRIP Change elevators, slips. UD 23 jts 5" HWDP, jars, bit. 09:30 13:00 3.50 7,910 7,910 AF RCMP EQUIP Pull wear bushing. RIU to run 3-1/2" EXCAPE completion. RIU casing crew, Pollard, Expro. RIU sheaves for control lines, lay out perf modules 1 - 9. Run control lines through sheaves. 13:00 22:30 9.50 7,910 7,910 AF RCMP CSG PJSM. Run 3-1/2", 9.3 ppf, l-80, Mod 8RD EUE casing wI EXCAPE perf modules & control lines. Modules 1 - 9 & Thoma the Tank in hole @ 22:30 hrs. 22:30 23:30 1.00 7,910 7,910 AF RCMP CSG Break circulation, circulate 2 casing volumes. Equipment performing as expected. 23:30 04:00 4.50 7,910 7,910 AF RCMP CSG PJSM. Continue running 3-1/2" EXCAPE completion & control lines to 9-5/8" casing shoe. Joint 140 out of 235 in hole. 04:00 04:30 0.50 7,910 7,910 AF RCMP CSG Break circulation @ casing shoe. Circulate 1 casing volume. 04:30 06:00 1.50 7,910 7,910 AF RCMP CSG Continue running 3-1/2" EXCAPE completion & control lines. Joint 167 out of 235 in hole @ report time. 5 BHA DESCRIPTION I 8-1/2" RR MX-1 Bit, Bit Sub, Heavy Weight Drill Pipe {4}, Drilling Jar, Heavy Weight Drill Pipe {19}, Cross Over Printed: 4/8/2004 9:50:13 AM Nabors Alaska Drilling 19 252.00 Expro 2 14.00 Marathon 1 24.00 BJ Services 2 6.00 Marathon EXCAPE Engineer 1 14.00 Weatherford 2 42.00 M-I Drilling Fluids 1 24.00 Weaver Brothers (WBI) 1 2.00 Epoch Well Services 2 24.00 Pollard Wireline 2 40.00 Expro 6 96.00 Lynden Transport 1 1.00 Printed: 4/8/2004 9:50:13 AM WELL NAME FALLS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS wac. Pre to P/U BOP to set sli s. OPERATION COMMENTS Run 3-1/2" EXCAPE completion casing. 16.5 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 7,993 MOCW! NR! _uu ·~·-:'L COST 9072831315 COUNTY/OTHER LEAKOFF Circulate casing. Run correlation log. Put casing on depth. Cement casing. WOC. BOP PSI TEST 2/1/2004 06:00 09:30 3.50 7,910 7,910 AF RCMP CSG Finish running 235 jts, OAL 7863.53',3-1/2",9.2 ppf, L-80, Mod 8RD completion casing including perf modules & pup jts. 09:30 13:30 4.00 7,910 7,910 AF RCMP CIRC RlU & circulate 3-1/2" casing. Reciprocate casing 15' while circulating. RID Expro. RID control sheaves, terminate control lines & sacriticialline. Move control line spools, remaining casing & pipe racks. Spot Expro wireline truck. 13:30 14:00 0.50 7,910 7,910 AF RCMP LOG RlU Expro loggers to run correlation log. 14:00 16:30 2.50 7,910 7,910 AF RCMP LOG Install lubricator. Run GRlCCL correlation log. POOH wI W/L. 16:30 17:00 0.50 7,910 7,910 AF RCMP LOG UD lubricator. P/U 6' pup joint, put casing on depth, lower 3-1/2" casing 7'. Bottom of float shoe @ 7865.98', top of float collar @ 7830.19' MD. 17:00 19:00 2.00 7,910 7,910 AF RCMP LOG Install lubricator. Re-run correlation log. POOH wI W/L. 19:00 19:30 0.50 7,910 7,910 AF RCMP LOG UD lubricator, RID loggers. 19:30 20:30 1.00 7,910 7,910 AF RCMP CEMT RlU to cement casing. Install cementing head & lines. 20:30 23:00 2.50 7,910 7,910 AF RCMP CEMT Circulate & reciprocate 3-1/2" EXCAPE completion while batch mix cement. 23:00 01:00 2.00 7,910 7,910 AF RCMP CEMT PJSM x 2. Cement casing as follows: Pump 5 bbls water & tes lines to 3000 psi. Mix & pump 34 bbls 10 ppg weighted spacer. Mix & pump 69 bbls lead cement + additives mixed @ 13.5 ppg, 1.84 cf/sk yield. Pump 257 bbls batch mixed lead cement + additives mixed @ 13.5 ppg, 1.84 cf/sk. Pump a total of 850 sx lead cement. Drop top plug. Displace cement wI 68.8 bbls 8.6 ppg 6% KCI. Bump plug wI 1800 psi. CIP @ 01:00 hrs, 2/9/2004. Chk floats, floats held ok. 01:00 06:00 5.00 7,910 7,910 AF XMBO NUND wac 8 hrs. RID cementers. Prep BOP stack for removal. Clean pits, shakers, haul mud to disposal. Move mud material to Abalone pad. Start RID floor. Prep split flow nipple for removal. Printed: 4/8/2004 9:50:18 AM Nabors Alaska Drilling Marathon Marathon M-I Drilling Fluids Epoch Well Services Expro LAST BOP TEST: 2/1/2004 19 252.00 BJ Services 1 24.00 Weatherford 1 21.00 Pollard Wireline 1 24.00 Airport 2 24.00 Weaver Brothers (WBI) 6 36.00 R&K Industrial 9.625 3.500 8.835 2.991 17.20 1,320 (psi) @ 9.50 (ppg) (psi) @ (ppg) 3,302 6,008 4,888 7,866 6 1 2 1 1 5 60.00 10.00 8.00 2.00 10.00 73.00 NEXT BOP TEST: 2/8/2004 40.00 9.20 L-80 L-80 5,750 10,160 Printed: 4/8/2004 9:50:18 AM 24 HR PROG TMD 16.5 7,910 RIG NAME & NO. AUTH MD NABORS DRILLING 129 7,993 RIG PHONE MOC WI NR! 9072831315 COUNTY/OTHER ~...,...n.urr 06:00 09:00 3.00 7,910 7,910 AF XMBO NUND WOC 8 hrs. Clean pits. Clean rig floor. UD kelly hose. Remove choke & kill line. Remove split flow nipple/flow line. Blowdown mud lines pump #1/#2. Unhook upper J-box electrical lines on T/D. Coil lines in grassshoper. 09:00 09:30 0.50 7,910 7,910 AF XMBO NUND UD tongs, mouse hole, prep catwalk to move. 09:30 10:00 0.50 7,910 7,910 AF XMBO NUND Install safety lines on BOP stack. RlU pick up slings. PIU BOP stack. Remove blind flange on side outlet, exit double 1/4" control lines from tubing head valve outlet. Terminate 1/4" control lines outside & 7/16" sacrificial line inside of well bore. Install flange on side outlet. Install 3-1/2" casing slips wI 72.5K of pipe weight. Make rough cut on 3-1/2" casing. 10:00 12:00 2.00 7,910 7,910 AF XMBO NUND UD casing cut-off. Finish RID casing tools, elevators, slips, UD long bales. Remove beaver slide. 12:00 16:00 4.00 7,910 7,910 AF XMBO NUND Set down stack. N/D BOPE. Remove annular, dbl ram, mud cross & DSA. Unplug TID. Continue clean pits. 16:00 17:00 1.00 7,910 7,910 AF XMBO NUND Make final cut on 3-1/2" casing. Clean pits. Move service loop in derrick. 17:00 18:00 1.00 7,910 7,910 AF XMBO NUND Install & test pack-off to 8000 psi for 15 minutes. 18:00 22:00 4.00 7,910 7,910 AF XMBO NUND P/U & swing in 3-1/16" 10M psi dbl master, single wing wI swab valve production tree. N/U tree. Install TWC valve. Test void t 5000 psi, neck seals & tree to 10,000 psi. Pull TWC valve, install BPV. Top off wI methanol, secure tree cap. 22:00 02:00 4.00 7,910 7,910 AF RDMO EQUIP RD drilling equipment. Clean up around mud pits, shakers & cuttings tanks. RID gas buster. Tieback service loop. 02:00 06:00 4.00 7,910 7,910 AF RDMO EQUIP UD stabbing board, mud manifold, clean rig floor, clean mud pits. Remove electrical & hydraulic service loop fl T/D. Unbolt torque tube. Power wash outside of pits for rig move. Continue RID drilling equipment. RDMO. Printed: 4/8/2004 9:50:19 AM AVG. CONN: MAX. CONN: Nabors Alaska Drilling Marathon M-I Drilling Fluids Epoch Well Services Expro Weaver Brothers (WBI) 19 252.00 R&K Industrial 6 72.00 1 24.00 Airport 1 0.50 1 12.00 S&R Enterprises 2 1.00 2 20.00 S&R Enterprises 1 1.00 3 12.00 Mike's Delivery Service 1 0.50 2 20.00 LAST BOP TEST: 2/1/2004 NEXT BOP TEST: 2/812004 9.625 3.500 8.835 2.992 17.20 1,320 (psi) @ 9.50 (ppg) (psi) @ (ppg) 4,888 7,866 3,302 6,008 40.00 9.20 L-80 L-80 5,750 10,160 Printed: 41812004 9:50:19 AM WELL NAME FAllS CREEK 4 SUPERVISOR Gene Anderson FIELD NAME 24 HR PROG TMD 16.5 7,910 RIG NAME & NO. AUTH MD NABORS DRilLING 129 7,993 R!G PHONE MOC WI NRJ 9072831315 COUNTY/OTHER . r.!!!.II WF!! r.:n~T LEAKOFF Clean pits, insideloutside of cuttings tanks. Vac out suction tan & flow trough. Remove cutting tanks. Clean herculite under tanks. Remove desilter discharge line, degasser stack. Raise shaker walkway deflate boots, prep pits for move. UD T/D. Install bridle line PIU device, bridle up. Fold up grasshopper. Shut down generator. RID pits. UD derrick. RID derrick. RDMO drilling equipment. Release rig to Paxton #1 @ 12:00 hrs, 2/10/200. units 2/8/2004 BURST si 5,750 10,160 Printed: 4/8/2004 9:50:20 AM WELL NAME FALLS CREEK 4 SUPERVISOR Ken Rourke FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS 16.5 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE MOCW! NR! ........II..c~:11 "'^C!T 9072831315 COUNTY/OTHER LEAKOFF OPERATION COMMENTS RU Reeves Electric line Run CBL log. RD Wireline 09:00 10:00 1.00 MIRU WIRELN Reeves wireline arrived on location. 10:00 11:00 1.00 MIRU WIRELN RU wireline to wellhead. Hook-up vac truck to flow line to take wireline displacement returns. 11 :00 11:30 0.50 MIRU WIRELN Held safety meeting with other operations in the area. 11 :30 14:00 2.50 OTHER LOG TIH with CBL tool to 7768' wlm checking PU. PU and begin logging hole at 30 fpm. Logged to 200' above top of cement 14:00 15:00 1.00 RDMO WIRELN RD Reeves wireline. Turned well over to production. Returned t Gas Field with logs. (psi) @ (ppg) Printed: 4/8/2004 9:56:21 AM WELL NAME FAllS CREEK 4 SUPERVISOR Jim Thom son FIELD NAME WilDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Warmin U frac e . Holdin OPERATION COMMENTS Complete rigging up all frac eqp and lines. Perforated module one perfs. Pressure tested coil tbg lines and flowback to 4500 psi. shut down for 16.5 RIG NAME & NO. NABORS DRilLING 129 RIG PHONE 7,910 AUTH MD WBS MOeW! NR! 9072831315 COUNTY/OTHER LEAKOFF . 'et well in. 13:00 15:00 2.00 AF PERF PERF RU frac eqp and lines. RU folwback lines and well testing eqp. RU coil tbg injector head. Hold PJSM. RU all lines and test. Perforating with Expro Syste fl 7644 to 7654. RD all eqp. Finish RU frac eqp. Spot Expro perforating trailer. Held PJSM test coil tbg and flowback lines to 4500psi. SDFN 15:00 19:00 4.00 AF MIRU STIM (psi) @ (ppg) Printed: 4/8/2004 9;56:24 AM SUPERVISOR Jim Thom son FIELD NAME 16.5 RIG NAME & NO. WBS RIG PHONE MOCWI HRI WilDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS / MTS Pre ann to POOH with coil tubin to 'et well in. same OPERATION COMMENTS Fracture treated 9 excape modules. RD frac equipment. RU coil tubing. RIH with coil tubing, Break flappers for excape modules 6,5,4,3, and 2. Attempt to locate flappers for excape modules 9,8,and 7 with out success. 06:00 07:00 1.00 AF STIM TEST Start up frac trucks and equipment and warm up same. Hold pre-job safety meeting (PJSM). 07:00 09:00 2.00 AF STIM TEST Fill treating lines and pressure test frac equipment and lines to 9500 psi. Gel fluid and bucket test chemical pumps. Perform breaker tests to confirm fluid system recipe. Prepare to perform injectivity test into module one perfs. 09:00 09:30 0.50 AF STIM STIM Perform injectdivity test into module one perfs. Pumped 50 bbls of gel fluid at 15 BPM. Shut doewn pumps and monitor bleed off for ISIP. ISIP = 4658 BHP for a FG of 0.8 psilft. Prepare to frac module one. 09:30 10:00 0.50 AF STIM STIM Frac mod 1 perfs wI BJ Lightning_ V _1800 wtr based system at 15 BPM at max TP = 4300 psi. Ramp 2.0 - 8.0 ppa. Place 32,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot load = 229 bbl. Tagged wI ProTechnics CFT 1100 chemical tracer and Sc-46 and Ir -192 RA markers iin pad and slurry volumes, respectively. 10:00 10:30 0.50 AF STIM STIM Fire Expro gun mod No.2 with 3050 psi perf interval 7,300' - 7,310' MD. Frac wI BJ Lightning_V_1800 wtr based gel at 15 BPM at max TP = 4500 psi. Ramp 2.0 - 8.0 ppa. Place 32,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot load = 284 bbl. Tagged wI ProTechnics CFT 1200 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 10:30 11:15 0.75 AF STIM STIM Fire Expro gun mod No.3 with 4450 psi perf interval 6,664' - 6,674' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 3800 psi. Ramp 2.0 - 8.0 ppa. Place 31,800 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot load = 252 bbl. Tagged wI ProTechnics CFT 1400 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. Printed: 4/8/2004 9:56:26 AM 11 :15 12:15 1.00 AF STIM STIM Fire Expro gun mod No.4 with 5530 psi perf interval 6,436' - 6,446' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 3420 psi. Ramp 2.0 - 8.0 ppa. Place 32,400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 253 bbl. Tagged wI ProTechnics CFT 1500 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 12:15 12:45 0.50 AF STIM STIM Fire Expro gun mod No.5 with 6500 psi perf interval 6,028' - 6,038' MD. Frac wI BJ Lightning_V_1800 wtr based gel at 15 BPM at max TP = 3300 psi. Ramp 2.0 - 8.0 ppa. Place 31,400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 249 bbl. Tagged wI ProTechnics CFT 1600 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 12:45 13:15 0.50 AF STIM STIM Fire Expro gun mod No.6 with 7560 psi perf interval 5,922' - 5,932' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 8.0 ppa. Place 31,400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 246 bbl. Tagged wI ProTechnics CFT 1700 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 13:15 13:45 0.50 AF STIM STIM Fire Expro gun mod No. 7 with 8590 psi perf interval 5,832' - 5,842' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 2900 psi. Ramp 2.0 - 8.0 ppa. Place 31,400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 259 bbl. Tagged wI ProTechnics CFT 1900 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 13:45 14:15 0.50 AF STIM STIM Fire Expro gun mod No.8 with 9700 psi perf interval 5,570' - 5,580' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 2830 psi. Ramp 2.0 - 8.0 ppa. Place 30,200 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 240 bbl. Tagged wI ProTechnics CFT 2000 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. 14:15 14:45 0.50 AF STIM STIM Fire Expro gun mod No.9 with 10700 psi perf interval 5,516'- 5,526' MD. Frac wI BJ Lightning_ V _1800 wtr based gel at 15 BPM at max TP = 2820 psi. Ramp 2.0 - 10.0 ppa. Place 34,20 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 267 bbl. Tagged wI ProTechnics CFT 2100 chemical tracer and SC-46 and Ir-192 RA markers in pad and slurry volumes, respectively. Monitor fall off pressure for 15 miniutes. 14:45 18:00 3.25 AF STIM EQUIP Rig down frac lines and equipment. Rig up coil tubing injector head and stab same onto wellhead. Transfer 6% KCL from frac tanks to coil tubing suction tank. Purge expro dead string with helium and hook up BJ transducer to same. 18:00 23:00 5.00 AF STIM CL TBG Run in Hole with Coiled Tubing and clean out to 5938'. Found Printed: 4/8/2004 9:56:26 AM 18:00 23:00 5.00 AF STIM CL TBG no indication of flappers for modules 9,8, or 7. While attempting to locate flapper for module 6 with pumps off, nozzles plugged off on washljet tool. Pooh to clean out nozzles 23:00 23:30 0.50 AF STIM CL TBG Pick up injector head, clean frac sand out of nozzles. Satb injector head. 23:30 04:00 4.50 AF STIM CL TBG Run in Hole with Coiled Tubing and break flappers at 5947' (mod 6),6054' (mod 5), 6462' (mod4), 6689' (mod 3), and 7327' (mod 2). Continue RIH to PBTD of' and CBU. 04:00 06:00 2.00 AF STIM CL TBG Pull out of Hole with Coiled Tubing to 5500'. RIH with coil tubin attempting to locate and break flappers for mod 9, 8, and 7 without success. Prepare to POOH to jet well in. Printed; 4/8/2004 9;56;26 AM FALLS CREEK 4 SUPERVISOR Jim Thom son F!ELD NAME 16.5 RIG NAME & NO. RIG PHONE MOCV'.~ ...01 COUNTY/OTHER LEAKOFF u well into test se arator , and test well POOH with CT and monitor well. Well loading up. RIH with CT and jet well in 06:00 06:30 0.50 AF STIM CLTBG Pull out of Hole with Coiled Tubing to 1500'. 06:30 07:30 1.00 AF STIM CL TBG Jet well in with 500 scfm N2. Well on half inch choke and WHP = 320 psig. 07:30 08:30 1.00 AF STIM CLTBG RIH to 3000' with coil tubing while jetting well in with 500 scfm N2. Well flowing. 08:30 09:00 0.50 AF STIM CLTBG Pooh with coil tubing while jetting with 500 scfm N2. 09:00 12:30 3.50 AF STIM FLOW Monitor well for continuous flow and unloading. Begin taking samples for chemical tracer analysis. Well not stable, loading up. Prepare to RIH with coil tubing. 12:30 14:00 1.50 AF STIM CL TBG Hold PJSM. RIH with coil tubing jetting with 350 scfm to 5000'. 14:00 15:30 1.50 AF STIM CLTBG Increase N2 rate to 500 - 750 scfm and continue jetting well in. 15:30 16:00 0.50 AF STIM CLTBG RIH with coil tubing jetting with 350 scfm. Verify top three module perfs were open. No flappers located. Perfs clean. 16:00 17:30 1.50 AF STIM CLTBG Pull out of Hole with Coiled Tubing jetting with 350 scfm. Shut in well. RID coil tubing injector head. Secure coil tubing unit. SO coil tubing operations for the night. 17:30 03:30 10.00 AF FLOW FLOW Flow Well and monitor over night for continuous flow and fluid unloading. Well started making gas with increased fluid volumes. Put well to test separator. 03:30 06:00 2.50 AF FLOW FLOW Flow Well into test separator. At 0530 total fluid recovered = 61 bbls (26.2% of 2329 bbl total frac load volume). Well flowing at 374 MCFO, 1008 BWPO with a 375 psig FTP. Recovered abou 6-8 oz (1 cup) of frac sand out of sand buster so far. Marathon Veco Printed: 4/8/2004 9:56:31 AM LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 3.500 (psi) @ (ppg) Printed: 4/8/2004 9:56:31 AM WELL NAME FALLS CREEK 4 SUPERVISOR Jim Thom son FIELD NAME 16.5 RIG NAME & NO. WBS RIG PHONE MOCWI NRI WILDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Flowin and cleanin OPERATION COMMENTS Flow well to test separator. Put well in sales at Midni LEAKOFF Flow Well to test separtor. Well continually improving with flowrates going from 375 mscfd, 624 bwpd, FTP = 375 psig on 32164th choke at 0530 2-28-2004 to 2.155 mmscfd, 96 bwpd, FTP = 895 psig, on 32/64th choke at 0530. Estimated BHP from bubble tube at 0530 3-29-2004 = 1189 psig for estimated 32% drawdown of top perfs. Have 1000 bbls total fluid recovery (43% of 2329 bbl total frac load) Put well into sales at midnight (OOOO hrs) 3-29-2004. Released well and reporting requirements to production at 0600 hrs 3-29-2004. LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 3.500 Printed: 4/8/2004 9:56:32 AM API: 50-133-2053300 RT-GL: 16.50' RT-THF: 16.20' 1842' FSL,2842'FWL,Sec.6, TiN, R12W, S.M. Tree cnx == 4-3/4" Otis I TOC (est.) - 300' above 9-5/8" shoe' Excape System Details - SHP monitoring line volume tank located from 5435' - 5471' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKS): Module 1 - NA Module 2 - 7327' Module 3 - 6689' Module 4 - 6462' Module 5 - 6054' Module 6 - 5947' Module 7 - 5857' Module 8 - 5596' Module 9 - 5543' Well Name 8. Number: County Or Parish: Perforations MD) BHP: Dated Completed: Prepared By: FC#4 TO - 7910' PBTD - 7829' of FC#4 Kenai lease: State/Prov. BHT: Completion Fluid: Surface Casino: 13-3/8", 68 ppf, K-55, STC @ 1840' Cmt wI 434 sks of class G at 12.5 ppg Int. Casing: 9-5/8",47 ppf, L-80, STC @ 4$88' Cmt wI 400 sks of class G lead at 12.5 ppg& 175 sx of class G tail at 13.5 ppg Prod. Tubing: 3-1/2",9.3 ppf, L-80, EUE8rd with 6.25" 00 control line protectors Cmt wI 850 sks of class G at 13.5 ppg Excape System Details - 9 Excape modules placed Green control line fires bottom 1 module - Red contolline fires top 8 modules - Ceramic flapper valves below each module except for Module 1 Perfs MD IRKS): Module 1 -7644'-7654' Module 2 -7300'-7310' Module 3 - 6684'-6674' Module 4 - 6436'-8446' Module 5 - 6028'-6038' Module 6·5922'-5932' Module 7 - 5832'-5842' Module 8·5570'·5580' Module 9 . 5516'·5526' (T 6% J. R. Thompson Last Revison Date: 2/25/2004 e Alaskaeness Unit ... Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 22, 2004 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Þü1chorage,AJ( 99501 Delivered by Courier RE: Marathon Oil Company CONFIDENTIAL Well Sa~p~ ~( '3 c;,- Marathon Cannery Loop No: 7 ). U]. - fll (~ '> '1 Marathon Paxton No. 1 ,¡O<-J-orð , {J J Marathon Falls Creek No.4 do 0 J. - ~.2 .:Ji ~ :l ~(,. "1"* It;' 0 Marathon J(asilof South No. 1RD ;to 1.-- \ Marathon J(asilof South No. LlL ~~ - :( \-1 -:t! t L "':, \ The following CONFIDENTIAL well samples are being forwarded to AOGCC as shown on the attached listi. When the samples have arrived, please confirm yonr receipt by signing one copy of this letter and returning to my attention at the letterhead address. Thank you, MARATHONOILCOMœANY f(á J(aynell Zeman Technical Assistant Reoeivedby ~'NJ ollJ Date: d ~ ~ ~ '---l -/ ,.-- frl' t ~r-\ · . Marathon Falls Creek No.4 (FC 4) CONFIDENTIAL Ninilchik Unit, Cook Inlet, Alaska Sec. 6, T-I-S, R-12-W, Seward Meridian API #: 50133205330000 6 Boxes - Well S 1 ampJes Falls Creek #4 Well Samples Depth From Depth To (Feet) (Feet) Box No. 1,860 2,960 1 2,960 3,940 2 3,940 5,000 3 5,000 6,040 4 6,040 7,000 5 7,000 7,910 6 #JlJ~ ~Ò?,-)^I e . FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David R. Costillo Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519 Re: Falls Creek #4 Marathon Oil Company Permit No: 203-221 Surface Location: 1842' FSL 2842'FWL, Sec. 6 TIN R12W, SM Bottornhole Location: 794' FSL 1910' FEL Sec. 1 TIN R13W, SM Dear Mr. Costillo: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Marathon Oil Company assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerel~ (~' ~--:::»~~.- -" ,-,,~- \ L_··__·--· _ \ Sarah Palin Chair BY ORDER gF THE COMMISSION DATED thislJ¿ day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. WúA- J 2-/ u./ 2..00.~ . . 1 a. Type of Work: Drill 0 RedrillD 1 b. Current Well Class: Exploratory 0 Development Oil D Multiple Zone 0 Re-entryD Stratigraphic TestD Service D Development Gas D Single zoneD 2. Operator 5. Bond: o Blanket D Single Well D 11. Well Name and Number: Name: Marathon Oil Company Falls Creek 4 ./ Bond No. 5194234 3. Address: P.O. Box 196168 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99519-6168 MD: 7911 ft TVD: 6031 ft Ninilchik 4a. Location of Well (Governmental se~~ 7. Property Designation: TyoneklUndefined Pool ADL 590 Surface: 1842' FSL 2842' ~ Sec. 6 T1N R12W 8. Land Use Permit: 13. Approximate 15-Jan-04/ NIA Spud Date: Top of Productive Horizon: 1084' FSL 706' FEL Sec. 1 T1N R13W 9. Acres in Property: 14. Distance to 564.45 acres Nearest Property: otal Depth: 794' FSL 1910' FEL Sec. 1 T1N R13W 1300ft 4b. Location of Well (State Base Plane Coordinates): 10. KB elevation 15. Distance to Nearest RKB-MSL 261.5 feet Well within Pool: 400ft Surface: x- 239980.9 y- 2269393.620 Zone- 4 (Height Above GL): 16.5 feet Marathon Fallscreek 3 Top of Middle B 16. Deviated Wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff Depth: 250 ft. Maximum Hole Angle: 63.51 0 Max. Downhole Pressure: 2426 psig. Max. Surface Pressure: 2395 / psig. 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks. Hole Casing Weight Grade Coupling Lenath MD TVD MD TVD (Including Stage Data) Driven 20 in. 133 K-55 Welded 101 ft 0 0 101 ft NIA 16 in. 13318 in. 68 K-55 BTC 1838ft 0 0 1838ft 1532ft 481 sacks 121/4 in. 9518 in. 40 L-80 BTC 4879ft 0 0 4879ft 3284ft 'tU/ ~sacks 81/2 in. 31/2 in. 9.3 L-80 8rd 7911 ft 0 0 7911 ft 6031 ft 889 sacks ,.. 19. PRESENT WELL CONDITION SUMMARY (to be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft.) Plugs (measured) Effective depth MD (ft) Effective Depth TVD(ft): Junk (measured) Casing Length Size Cement Volume MD TVD Struc1ural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee~ BOP Sketch ~ Drilling program~ Time v. Depth PlotD Shallow Hazard Analysis D Property Platl:&1 Diverter Sketch 00 Seabed ReportD Drilling Fluid Program ~ 20 AAC 25.050 Requirements D 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name David R. Castillo Title Senior Drilling Engineer Signature i:J&, ~~ ~ Phone 907-564-6465 Date December 18, 2003 Commission Use Only Permit to Drill .3 :2.2/ IAPI Numf?:? .~ .:{ ? I ~ermit Approval I ,r¡J h'h/O 'J} I ~ee cover letter for Number: 2D - 50- /. - 2ð Date: other requirements. Conditions of approval: Samples required DYes ~No Mud log required , DYes ~NO Other: Tt'st- Hydrogen sulfide measures DYes ~NO Directional survey required ~Yes DNO tOPE- fQ. 300~ rPeðtßy OnglOal Ig n.:- -ridJJ~ ~1á Sarah Palin BY ORDER OF Approved by: COMMISSIONER THE COMMISSION I "' L. '-' L.- I 'V'__ LJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 kt6A- ....8FL lEt 12 *' OR¡G DEC 1 ct' 2003 ,.\ L ~ ¡, t '" t'\ · Alaska Oil & Gas Cons. Commission Anchorage · It MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Falls Creek 4 PERMIT December 18, 2003 Originator: David R. Castillo Drilling Supervisors: Gene Anderson, Roland Lawson Drilling Superintendent: Peter Berga e e Table of Contents General Well Data........................................................................................................................... ........................................ 1 Geologic Program Summary.......................................................................................................................... .........................1 Summary of Potential Drilling Hazards........................................................................................................................ ............2 Formation Evaluation Summary.......................................................................................................................... ....................2 Drilling Program Summary........................................................................................................................... ...........................3 Casing Program............................................................................................................. ..........................................................4 Casing Design........................................................................................................................... ..............................................4 Maximum Anticipated Surface Pressure .................................................................................................................................4 BOPE Program.............................................................................................................. ..........................................................6 Directional Program Summary............................ .................................................................................................................... 7 Directional Surveying Summary.................................................................................... ..................... .....................................7 o - 1 837ft. . . . . . . . .. .. .... . . . . .. . . . . . .. .. . .. .. .. .. . . . . .. ... .. . . . . . .. . .. .. .. .. .. .. .. ... .. .. . . . . . .. .. . .. . . . . . .. . . . . . . . . . . . . . . . . . . . . .. .. .. .. .. .. . . . . . .. ..... .. . . .. . . . . .. . .. . . .. . . . .. .. .. .. .. . 7 1837 - 4879 ft......................... ........................................................................................................... ......................................7 4879 - 7911 ft................................................................................................................................... . ......................................7 Drilling Fluid Program Summary....................................................................................................... ......................................8 Drilling Fluid Specifications............................................................... ................................................. ......................................8 Solids Control Equipment................................................................. ................................................. ......................................8 Cement Program Summary................................................................................................................................. ....................9 Regulatory Waivers and Special Procedures.................................................................................... ......................................9 Hydraulics Summary ......................................................................................................................... ....................................10 Formation Integrity Test Procedure........................................................................................................................... ............10 e e General Well Data Ninilchik Kenai Borough Alaska 7911 ft 6031 ft NA DX.03.09624.CAP.DRL Jan 15, 2004 NA Exploitation Nabors 129 Falls Creek 4 X: 2269393.6200 Falls Creek 16.5 ft 245.0 ft RKB NA Y: 239980.9000 Comments: Geologic Program Summary Beluga B2 4979.59 3375 1,451 - 1,654 8.28-9.4 Sandstone Gas Beluga B3 5602.99 3940 1,694 - 1,931 8.28-9.4 Sandstone Gas Tyonek 6717.41 4950 2129 - 2,426 8.28-9.4 Sandstone Gas Comments: Township 1N, Range 12W Seward N 60012' 15.309" E 1510 25' 45.491" 2269393.6200 239980.9000 NAD27 ASP ZONE 4 Beluga B2 4980 3375 2268703.04 N, 236821.08 E -758.82 -3114.13 250 Beluga B3 5603 3940 2268464.79 N, 236563.69 E -820.64 -3400.24 250 Tyonek 6717 4950 2268413.98 N, 235628.00 E -931.13 -3858.06 250 TO 7911 6031 2268438.58 N, 235611.01 E -1029.59 -4266.03 250 Comments: page 1 of 10 e e Summary of Potential DrillinQ Hazards Lost Circulation SurgelSwabbing Keep the drill pipe moving and avoid if possible excess overbalance. Maintain low fluid loss and thin impermeable filter cake. Circulate hole clean before tripping. Do not POOH or RIH faster than 30 see/stand Differential Sticking Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. / Gas sands will be encountered from the top of the Beluga B2 at +1- 4,980 ft MD RKB (3375 ft TVD RKB) to total depth of the well. These sands will be normally pressured. Formation Evaluation Summary Surface None o ft - 1,838 ft MD Intermediate None 1,838 ft - 4,879 ft MD Production None 4,879 ft - 7,911 ft MD Completion N/A None Rig Watch/Basic Reeves - Quad Combo Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Cased hole- Gamma Ray/Neutron GRlNeutron, CCL N/A Coring Requirements: None Comments: EXCAPE Completion page 2 of 10 e e Drillin~ Pro~ram Summary CONDUCTOR: 1. Drive 20" conductor to +1- 100.5 ft. RKB. 2. Move in and rig up Nabors 129 rotary drilling rig. 3. Install starting head 20" SOW x 21 1/4", 2M flanged. 4. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. / 5. Function test diverter and diverter valve. SURFACE: 1. Drill a 16" hole to 1838 ft (1532 ft TVD) with Spud Mud. 2. RIH with 133/8" casing and hang off in the slips. Make up stab-in sub and centralizer on 4" drill pipe. TIH with inner string and latch into stab-in float collar. Cement 13 3/8" casing. Sting out and circulate drill pipe clean. TOOH with inner string. 3. PU 133/8" casing, set casing slips in 20", cut off 13 3/8", ND diverter. 4. Install 13 3/8" slip lock connection X 13 %" 5M-flanged multibowl wellhead. 5. NU 13 %" 5M BOP'S. Test BOP'S and choke manifold to 250/3,000 psi. / 6. Set wear bushing. - 7. Test surface casing to 2,000 psi. INTERMEDIATE: 1. 2. 3. 4. 5. 6. 7. 8. Drill out float equipment and make 20' of new hole. Displace spud mud with FloPro. Circulate mud until mud weight in equals mud weight out. Test shoe to leak-off. Estimated EMW is 14.53 ppg. Drill 12 1/4" directional hole to 4880 ft MD (3284 ft TVD) as per directional plan. Make wiper trip. Change out variable pipe rams with 9 %" casing rams. Run test plug and test BOP casing rams to 250/3,000 psi. Run and cement 9 %" casing. Land hanger in multibowl wellhead. Back out landing joint. Change out 9 %" BOP casing rams with variable pipe rams. Run test plug and test BOP pipe rams to 250/3,000 psi. / Set wear bushing. Test casing to 2,000 psi. ./ 9. PRODUCTION: 1. 2. 3. 4. 5. 6. Drill float equipment and 20' of new formation with an 8 y,," bit. Test shoe to leak-off. Estimated EMW 15.01 ppg. Drill an 8 y,," hole to 7911 ft MD RKB (6031 ft TVD) per the directional program. TOOH. RU logging company. Run open hole logs as per plan. RD logging company. TIH to TD for wiper trip. TOOH and lay-down BHA and drill pipe. Pull the wear bushing. Run 3 y,," EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging /' company. / Cement 3 y,," casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. / PU 3 y,," casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 3 y,," casing. LD BOP. Set 3 y,," packoff. NU 13 %" 5M X 3 Ys" 5M tubing head adapter and 3 Ys" 5M tree. Test tree to 5,000 psi. Rig down and move out drilling rig. Circulate mud until mud weight in equals mud weight out./ / 7. 8. 9. 10. Note: Perforating guns will be run on the outside of the 3 y,," production casing with a flapper valve just below each perforating gun. Guns are to be activated by a control line to surface. COMPLETION: EXCAPE completion will be finished without a rig. / page30f10 e e Casing Program 20 0 100.5 133 K-55 18.73 18.543 Driven 3056 1496 2125 13 3/8 0 1838 68 K-55 12.415 12.259 BTC 14.375 Diamond 16 3454 1949 1069 95/8 0 4879 40 L-80 8.835 8.750 BTC 10.625 Diamond 12 1/4 5745 3087 916 31/2 0 7911 9.3 L-80 2.992 2.867 8rd 4.5 3,200 81/2 10160 10535 207 Comments: Casing Design 20 130.1 K-55 100.5 NA NA NA NA 69.51 39.41 22.74 13% 68 K-55 1838 9.4 14.55 8.6 879 1.73 2.61 2.28 /' 9% 40 L-80 4879 9.6 14.94 9.38 1621 2.53 1.89 2.97 3Yo 9.3 L-80 7911 15.81 9.4 2395 1.3 3.51 1.99 Comments: Maximum Anticipated Surface Pressure 13% 9% 1532 3284 2700 4494 879 1621 2395 70/30 70/30 01100 3 Yo 6031 5000 * MAWP = Maximum Allowable Working Pressure. ** MASP = Maximum anticipated surface pressure page 4 of 10 e Comments: MASP calculated as the lesser of MASPfrac and MASPbhp 13 3/8 inch Surface Casinq TVDShoe:= 1532·ft TVDOH := 3284·ft F mud := 30% FG := 14.55·ppg pSI Pgas:= 0.1·- ft Pmud := 9.6·ppg MASP frac := FG· TVDShoe - (p gas' TVDShoJ MASP frac = 1005 psi BHP:= PP·TVDOH MASPbhp:= BHP - (Fmud·TVDORPmud) -[( 1- Fmud)·TVDORPgaJ MASPbhp = 879psi MASP:= mi~MASPfrac,MASPbhp) MASP =~ 9 518" Intermediate Casinq TVDShoe:= 3284· ft TVDOH := 6031·ft Pmud := 9.60·ppg FG := 14.94·ppg pSI Pgas:= O.l·ft F mud := 30% MASP frac := FG· TVDShoe - (p gas' TVDShoJ MASP frac = 2220 psi BHP:= PP·TVDOH BHP = 2945 psi MASPbhp := BHP - (Fmud·TVDORPmud) - (1 - Fmud)·TVDOH·Pgas MASPbhp = 1621 psi MASP := min(MASP frac,MASPbhp) MASP - t(¡),,¡ page 5 of 1 0 e PP := 9.38·ppg PP := 9.4·ppg e e 3 1/2" Production Casinq Modified Chevron Formula pSI C1 := -0.161·- ft C2 := 0.9394 C3 := 260'psi P gas := 0.65 TVDShoe:= 6031·ft PP := 9.4·ppg MASP := ( Cr P gas' TVDShoe) + ( C2· pp. TVDShoe) + C3 MASP &i BOPE Proaram (1) 13-5/8" Hydril GK 5M annular (1) 13-5/8" 5M pipe ram Intermediate 9% 4494 1621 2000 9.4 (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular f) (1) 13-5/8" 5M pipe ram Production 3Y:z 5000 2395 2500 (1) 135/8" 5M blind ram 25013000 , ..,.' (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets Comments: Blowout Preventers The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. page 6 of 10 e e Wellhead Equipment Summary Casing Head 13-%" 3M X 13-3/8" Slip Loc W/2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, PR1 13 %" x 9 %" Fluted Mandrel 13 %" x 3 Y:," Manual Slip Tubing Head 13-%" 3M Studded Bottom X 13-%" 5M Fig Top, W/2, 2-1/16" 5M Studded Outlets, U, AA, PSL 1, PR1 Adapter Flange 13-%" 5M X 3-%" 5M WI Seal Pocket and 3" H BPV Threads Comments: Directional Proaram Summary 1837.70 1532.02 4 0 4 63.51 256.45 -185.98 -771.41 793.51 3339.22 2201.71 0 0 0 63.51 256.45 -500.93 -2077.80 2137.33 4879.66 3284.37 -2.5 0 2.5 25 256.45 -748.18 -3103.30 3192.22 4979.66 3375.00 0 0 0 25 256.45 -758.08 -3144.39 3234.48 7910.52 6031.26 0 0 0 25 256.45 -1048.41 -4348.52 4473.12 Comments: BHI proposal 5585 Directional Survevina Summary 0-1837 ft 1837 - 4879 ft 4879 -7911 ft X X X Comments: page 7 of 1 0 - e Drillin~ Fluid Pro~ram Summary 0 1837 8.6 - 9.4 Gel I Gelex Spud Mud 1837 4879 9.0 - 9.6 Flo-Pro wI 6% KCL + Safecarb 4879 7911 9.0 - 9.6 Flo-Pro wI 6% KCL + Safecarb Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL Flo-Vis, PoluPac UL, KCI, SafeCarb F, Ventrol401, Barite, Caustic, Conqor 404, SafeScav NA Flo-Vis, DualFlo, KCI, Greencide 25G, SafeCarb F&M, Barite, Caustic, Conqor 404, SafeScav NA Comments: Drillin~ Fluid Specifications o 1837 4879 1837 4879 7911 8.6 - 9.4 9.0 - 9.6 9.0 - 9.6 60-100 25-35 9-12 10-14 40,000 40,000 NC-12 8-10 ±7.5% ±5% <6 ± 9.5 ± 9.5 ± 9.5 <7% Comments: Mllntegrated Fluids Engineering Plan, Dec 11th, 2003 Solids Control Equipment 1 - Derrick Model 200 flowline cleaner 1 - Swaco centrifuge unit Marathon G&I Facility Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. page 8 of 10 e e Cement Pro~ram Summary 13 % 1838 4879 7911 1532 3284 6031 12y.. 16 o 3379 4479 o 2219 2938 825 470 1135 1290 739 1635 50% 50% 50% 9% 3Y> 8Y> Comments: Excess calculated on 50% of gauge hole in the open hole. If a 4-arm caliper is run before the cement job, a cement volume with 25% excess over the caliper will be used. Class "G" 12.5 2.1 470 9% Class "G" 13.5 146 1.84 269 3Y> Class "G" 13.5 889 1.84 1635 101 Fresh Fresh Fresh 190 16 o o 1088 902 Comments: BJ Proposa1100182146A, Dec 8th, 2003 Re~ulatorv Waivers and Special Procedures Requirement for 2 pipe rams, one blind ram, and one annular for a API 5K or above BOP stack. Comments: Marathon is requesting a waiver from the above regulation for the Falls Creek 4. Marathon requests that the BOP stack __ be configured with one pipe ram instead of two, due to rig height restrictions in the running of the 31/2" production casing. The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 3 1/2" casing is cemented and the BOP stack is picked up. This is before setting the casing on slips and cutting the casing sticking up. These lines control firing of the perforating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. A similar waiver was requested for the offset Kenai field gas wells KBU 43-7X and KBU 33-6X. No problems were encountered while doing this operation on the above wells. , ~ofE ~~t- L <£000 f<--.t :. ,...w WrM.V~ ýefr~N'd. page 9 of 1 0 e e Hvdraulics Summary Rig mud pumps available are shown below. 3 National Oil Well A600PT 6.5 6 5.5 9 9 9 2,745 3,233 3,846 3.68 3.14 2.64 120/1324 120/1130 120/950 Surface Intermediate Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. 1 -12 1400 16 635 2400 60 9.5 1 - 14 Hughes Hydraulics, version 1.70 2 -16s 6588 3 -18s Hughes Hydraulics, version 1.70 12.25 670 3200 60 9.8 1 - 15 9113 8.5 520 3100 60 9.8 3-20s Hughes Hydraulics, version 1.70 Comments: Assume 4" drill pipe Formation Intearitv Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test the 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 the 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 IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. page 1 0 of 10 DMR1£R NIN1IUI/ NORMAU.Y 0PfN. fMt'-VALI'!: NORMAU.Y CUJSE). -.-., - .._ r--''!-~ .. ...J;'1 c:tD:5£ I· i i 1 f--"~'" I' - . I r·-l , !iI¡-··-l ..J' .j f. 2. HrDfifI. IISP 21 1/." 2000PSI N/MIIAR I I I I I -L I DMR1£R SFOOI. API 21 f/." -2OOOPSI FWIŒS ....... ..... & ,.-c fMt'-VAl.I'!: f6" FIG. 66 KNlFF VALl'!: NISI f50 FWIŒS I)IVERTER CONFIGURATION -~ ~~ ~ n NABORS ALASKA RIG 129E GENERAL ARRANGEMENT !!. CM.y'..M.mtõIiZED~...-__~ eNll6cnAIaIM ="0 -=:. '=',;- .--- -.--- 107-283-«100 ø:r NABORS ALASKA RIG 129 G£Na1AI. ARRANGOIE1IT 12" DNEI1ÆI1 S'ISIDi 21-1/'" MH1JR 11- 'I!.t Iæf£ I~ SIIIH I........ '" PNA. SIIIH ~ mu ~ 110I: JJ IJIIÇ, NIl. 129_0001 ¡of' ~__(".IIE. 71 -- A IJA. 'iT 2fOCß/J ... ... IJ 5/8" 5000l WP HYDRIL, TYPE "GI(" IJ 5/8" 50001 WP ,/ SCREWED TOP BY IJ 5/8" FlANGED BOTTOM ANNULAR BOP HEIGHT = 51.25" 9'-~" IJ-5/8" 50001 HYDRIL ., DOUBI.£ G41E PREVENT OR ) IJ-5/8" 50001 WP \ FlANGED TOP AND BOTTOM HEIGHT = 54" MANf.W.LY OPERATED 2-1/16" 5.0001 WP G4Æ VALVE J" CHOKE UNE - - ~ HYDRAUL. ACIUATED J-1/16" 10.0001 WP ~ II G4Æ VALVE . \ MANUALLY OPERATED J-1/16" 5.0001 WP G4Æ VALVE IJ-5/8" 50001 API FlANGED TOP AND BOTTOM MUD CROSS W/ ONE (1) 4-1/16" (CHOKE UNE) 6: ONEi') J-1/16" (KILL UNE) 5,000 API FlANGED 0U1l.£lS NABORS ALASKA RIG 129 BOP STACK CONFIGURATION 16OfCOJ A JA. P.$. _1IIIf' ""'" ÆII_ at """"'" - '1[' "*" -- .. ~~fIf -NabanNœla =-O'=:. '::."::. .. .__.... ~ 1HOJ-2IJI NABORS ALASKA RIG /29 8I.OIIOOT PIIf1ÆNTEI/ 5/"ACK CONfIGfII1A1ION ; of , 6' x .. W··X6· NABORS ALASKA RIG 1 - WELL RETURNS ..... MUD MIX MUD SYSTEM SCHEMATIC HOPPER f2:. A.f2· .~ .~ 6·x.· A'" ~·K6· NOT SHOWN ARE TANK CLEANOUTS ~¡¡: 8' SUMP SUCTION OR STEAM LINES .~ ... ~ 6;h MUD MIX HOPPER r ~ -~ 6' SHALE SHAKE~ ~HALE SHAKER I A. 6' -wwww u n Ah .. U .~ I Ah6-1 6' DESIL TER L~ Ah ... .. TO SUMP 6- 6:'~ I 6:'h - ~ .. ... DISCHARGE 6~ 6' 6' A. ~ MANIFOLD j ~~: 6' ,r .. SAND TRAP 1õLJ '''6' 6' .( L,iij :;rr :;rr::::=' ~. :;rr I ~ ~ l6!6'~ .. :;rr 6:'h 6- fO- ~- ;:J fO' I ~ ... u~ ~ 6' fO' 6- ~ 10" 6;5: 5 X 6 :J5' K 6- l Y- Oh' ¡ CENTRIFUGALS tAL 6- 6' .. 6' 6- 6' 6- t ~ 6:'h 1õI:JJ"~6- _ ~ 5:6' X .:>::: }( }( .:>::: }( .:>:::}( ~ I}( t ... Jt:6' Ah6' 6- 6' 6' 6' 6- u ':>:::8- ~ ~ ~ ~'''6' 8' 8- ~\ 6' K 8' ( ~ J' ""'" (~ J' ~ ~ ~ Y- ~ (~ J- f (~- - (~ J- /~ ¡¡: ! ~¡¡: I ~ J- ! ~ J- / ~ aJ \ / / / / / J' : I ~ FROM IJ9Bbl'''1 1167 Bbl. "I 1167 Bbl. "I 1174 bl. AI 1197 Bbl. AI 1196 Bbl. "I MANIFOLD 24J Bbl. A I I 41 Bbl. " I 149 Bbl.GI 1207 Bbl. GI 1207 Bbl. GI 1216 Bbl. GI 1245 Bbl. GI 1244 Bbl. GI - J02 Bbl. G I I 51 Bbl. G I PILL TANK 8- "( 6' K J' AhJ' TRIP TANK 36" MUD GAS u SEP ARA TOR 8" FLOW LINES TO MUD PUMPS TO FLARE I --D- CONCENTRIC REDUCER ® BOTTOM MUD GUN LOW PRESSURE TYPE I TOTAL ACTIVE VOLUME = 1183 Bbls. I - GATE VALVE I TOTAL GROSS VOLUME = 1470 Bbls. I }( AGITATOR . =-.~. __~CIf' -1NJ- BUTTERFLY VALVE CNI FLANGES ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH ft~ Mabon AIaIkG 0.-. h:. GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK 2525 c Sbwt SIAl 200 ~ - ........... 107- eooo -g- SUCTION VALVE, TEE TYPE ( NOT INCLUDING TRIP TANK) NNJORS A!AS/(¡\ RIG 129 ~K EQUALIZER OR SKIMMER IIIJO SYSÆJI salEllAT1C 118J 8fI. AClM SlStD/ ~ SUCTION VALVE. ELL TYPE ";a ALSroN I~ SJI1I 1-·' /MIL SJI1I 1-' - REF: I/ODCSON INIJUõfR/AL O£SIGN Lro. DIIC. NO. RJ052-o5 ..,. .'1'11 ..... .......... I~ Hlo I~&næ. am 1- - t29J)QQJ 1-; '" , e Surface Use Plan for Falls Creek 4 - Surface Location: NE 1/4 of SW 1/4, Sec. 6, T1 N, R12W, S.M. 1. Existing Roads The Sterling Highway will be used for access to the Falls Creek well site and is shown on the attached map. Clam Gulch, Alaska is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed Road access and drilling pad already constructed. 3. Location of Existing Wells Falls Creek #1 RD and Falls Creek #3 are on the existing pad. A pad drawing is attached that shows the existing wells. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities on the Falls Creek pad are shown on the attached pad drawing. The Falls Creek 4 will use the existing production facilities and will require only the addition of a new flow line and methanol skid. 5. Location of Water Supply An existing water well previously drilled to a point below any local potable drinking water sources will be used. 6. Construction Materials None required for this operation. 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" disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage 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). Page 1 of 2 e Surface Use Plan for Falls Creek 4 e 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. Approximatelyfourtrailer 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. S & R will collect and transport sanitary wastes to their ADEC 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 all wells. 10. Surface Ownership Lee Pederson is the surface owner of the land at the Marathon Falls Creek Pad. 11. Operator's Representative and Certification 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. Signature: ~~.~ Date: December 18, 2003 David R. Castillo Sr. Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6465 Page 2 of 2 POINTS. 2. BASIS OF VERTICAL CONTROL WAS FROM NGS MONUMENT L82AT -f ,800 N:2,269,300 E: 240,500 + 0 EXPLORATION PAD FALLS CREEK NO.3 WELL 20" WELL CASI ELEV '" 249.0 ø 8' CIA. CELLAR @ j FALLS CREEK NO.4 WELL @ !1 [::J 181 o NOTES HEA POWER TRANSFORMER PHONE PEDESTAL GAS I WATER WELL LOCATION N:2,269,451.20 E:239,837.18 ELEV. '" 249.72' ~ cr: o o '" >- ~ :r: (!) I (!) z ::J cr: LU f- en ¡¡ . " . ~ ~ ~ ~ ~ ~;~g \,;r ,,(ííN-,;, .~ ~~~~ ¡ ¡ ~!iJ ð ~ ~~~ I ~~ t;H j oxN' \J ;0r:".;.¡ ::F ~~~~ GO:~"" ffi ~ > > ~ ß ij o $ ~ ~ ~I o ~I o LU (!) a LU ~. / FALLS CREEK NO. WELL I LEGEND / ~/// 4 þ 0<''' þ<v'l- {' 0~ ~0 ,¡. ~~'<Y' /",0 ?\ . / FOREST / SCALE / CONTROL POINT#2 50 N: 2,269,744.60 ...l..--....L E: 240,118.26 ~ / N: 2,269,700 / ~:239,900 / t N:2,269,700 ~ ",.,,," A- +E' 240.400 '"-.. ;, ,,,",,,,- POWER POLE r --ø- ~~\,)",~~\...ç'\,?'Ç.""- >-0 Z« «a... CLZ .¿ º ~ 0< =:; U G:: "? :::! 9 :< O a... >- XI- w _ Z ~ == Ow(j I~~ I-(j «(/) 0:::--, « « '¿LL ~ ~ ~ ê ~ ~ ~ ~ CMP 8"x50' ~ 8 g ~ ~ ~ ~ g ~ m ~ ~ ~ ~ ~ ~ ~ FOREST FALLS CREEK PAD AS-BUlL T ~]w 4 · e MARATHON Oil Company Creoted by bmichoel Structure: Falls Creek Unit # 1 Well: FC-4 Dote plotted; 11-Dee-ZOO3 Plot Reference ís FC-4 Versìon#1 Field : Falls Creek Field Location : Kenai Peninsula. Alaska Coordinates ore ìn feet reference slot #4, WELL PROFILE DATA True Vertical Depths orE reference RKB (Nabors 129). ---- ---- rl.:i'll BAKER HUGHES ----- Point ----- MD '00 Dír TVO North East V. Sect Oeg/100 INTEQ Tie on 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Kap 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 End of Build/Turn 1837.77 63.51 256.45 1532.02 -185.98 -771.41 793.51 4.00 End of Hold 3339.22 63.51 256.45 2201.71 -500.93 -2077.80 2137.33 0.00 0 400 800 1200 1600 -----. ...... 2000 (j) (j) -- '-.../ 2400 ..s::: ...... 0.. (j) 0 2800 0 0 3200 ...... L (j) > 3600 (j) ::::¡ L I- 4000 I V 4400 4800 5200 5600 6000 6400 25.00 256.44 3284.37 -748.18 -3103.30 3192.22 2.50 25.00 256.44 3375.00 -758.08 -3144.39 3234.48 0.00 25.00 256.44 5850.00 -1028.60 -4266.35 4388.59 0.00 25.00 256.44 6031.26 -1048.41 -4348.52 447.3,12 0.00 <- West (feet) 4500 4000 3500 3000 2500 2000 1500 1000 500 0 KOP of Drop/Turn 4879.66 FC-4 Belugo B2 4979.66 End of Hold 7710.52 T.O. & El\d of Hold 7910.52 ! RKB Elevation: 261.4' KOP 2.00 6.00 10.00 DLS: 4.00 deg per 100 it 14.00 18.00 22.00 26.00 30.00 34.00 42.00 50.00 ~ 58.00 ~ EOB - 13 3/8 Casing PI. FC-4 TO Tgt 10-Dee-03 TD - 3 1/2 Casing pt o EOB - 13 500 VI ~ EOD - 9 5/8 Casing pt C-4 Beluga 82 Tgt 10Dec03 TANGENT ANGLE 63.51 DEG 8e~7~9ap 56.99 51.99 DLS: 2.50 deg per 100 it 46.99 41.99 36.99 31.99 29.49 26.99 EOD - 9 5/8 Casing pt FC-4 8eluga 82 Tgt 10Dee03 FINAL ANGLE 25 DEG FC-4 TO Tgt TD - 3 1/2 o 4800 3600 4000 4400 400 800 1200 1600 2000 2400 2800 3200 Vertical Section (feet) -> Azimuth 256.45 with reference 0.00 N, 0.00 E from slot #4 ! 1000 , v 1500 e e MARATHON Oil Company Falls Creek Unit #1 FC-4 slot #4 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-4 Version#l prop5585 Date printed Date created Last revised 11-Dec-2003 11-Dec-2003 ll-Dec-2003 Field is centred on 242770.254,O.OOO,999.00000,N Structure is centred on 242770.254,2267493.144,999.00000,N Slot location is n60 12 15.309,w151 25 45.491 Slot Grid coordinates are N 2269393.620, E 239980.900 Slot local coordinates are 1840.36 N 2829.48 W Projection type, NAD27 ASP ZONE 4 Reference North is True North - e MARATHON Oil Company PROPOSAL LISTING Page 1 Falls Creek Unit #1,FC-4 Your ref FC-4 Version#l Falls Creek Field,Kenai Peninsula, Alaska Last revised : 11-Dec-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 0.00 250.00 0.00 N 0.00 E 0.00 0.00 KOP 300.00 2.00 256.45 299.99 0.20 S 0.85 W 4.00 0.87 400.00 6.00 256.45 399.73 1. 84 S 7.63 W 4.00 7.85 500.00 10.00 256.45 498.73 5.10 S 21.16 W 4.00 21.76 600.00 14.00 256.45 596.53 9.97 S 41.36 W 4.00 42.55 700.00 18.00 256.45 692.63 16.43 S 68.15 W 4.00 70.11 800.00 22.00 256.45 786.58 24.44 S 101.40 W 4.00 104.30 900.00 26.00 256.45 877.92 33.98 S 140.93 W 4.00 144.97 1000.00 30.00 256.45 966.20 44.98 S 186.56 W 4.00 191.90 1100.00 34.00 256.45 1050.98 57.39 S 238.06 W 4.00 244.89 1200.00 38.00 256.45 1131.87 71.17 S 295.19 W 4.00 303.65 1300.00 42.00 256.45 1208.46 86.23 S 357.67 W 4.00 367.92 1400.00 46.00 256.45 1280.38 102.51 S 425.19 W 4.00 437.37 1500.00 50.00 256.45 1347.28 119.92 S 497.42 W 4.00 511.67 1600.00 54.00 256.45 1408.83 138.39 S 574.01 W 4.00 590.45 1700.00 58.00 256.45 1464.74 157.81 S 654.59 W 4.00 673.34 1800.00 62.00 256.45 1514.73 178.11 S 738.76 W 4.00 759.93 1837.77 63.51 256.45 1532.02 185.98 S 771. 41 W 4.00 793.51 EOB - 13 3/8" Casing Pt. 2000.00 63.51 256.45 1604.38 220.01 S 912.56 W 0.00 938.70 2500.00 63.51 256.45 1827.39 324.89 S 1347.60 W 0.00 1386.21 3000.00 63.51 256.45 2050.41 429.77 S 1782.65 W 0.00 1833.72 3339.22 63.51 256.45 2201.71 500.93 S 2077.80 W 0.00 2137.33 Begin Drop 3400.00 61.99 256.45 2229.53 513.60 S 2130.33 W 2.50 2191.37 3500.00 59.49 256.45 2278.41 534.04 S 2215.13 W 2.50 2278.60 3600.00 56.99 256.45 2331. 04 553.97 S 2297.79 W 2.50 2363.62 3700.00 54.49 256.45 2387.32 573.34 S 2378.13 W 2.50 2446.27 3800.00 51.99 256.45 2447.16 592 .11 S 2456.01 W 2.50 2526.38 3900.00 49.49 256.45 2510.44 610.26 S 2531.27 W 2.50 2603.80 4000.00 46.99 256.44 2577.03 627.74 S 2603.79 W 2.50 2678.39 4100.00 44.49 256.44 2646.82 644.53 S 2673.41 W 2.50 2750.00 4200.00 41.99 256.44 2719.66 660.58 S 2740.00 W 2.50 2818.50 4300.00 39.49 256.44 2795.42 675.88 S 2803.44 W 2.50 2883.76 4400.00 36.99 256.44 2873.96 690.39 S 2863.61 W 2.50 2945.66 4500.00 34.49 256.44 2955.12 704.08 S 2920.39 W 2.50 3004.07 4600.00 31.99 256.44 3038.75 716 . 92 S 2973.68 W 2.50 3058.88 4700.00 29.49 256.44 3124.69 728.90 S 3023.37 W 2.50 3109.99 4800.00 26.99 256.44 3212.78 739.99 S 3069.36 W 2.50 3157.31 4879.66 25.00 256.44 3284.37 748.18 S 3103.30 W 2.50 3192.22 EOD - 9 5/8" Casing pt 4979.66 25.00 256.44 3375.00 758.08 S 3144.39 W 0.00 3234.48 FC-4 Beluga B2 Tgt 10Dec03 5000.00 25.00 256.44 3393.44 760.10 S 3152.74 W 0.00 3243.08 5500.00 25.00 256.44 3846.59 809.63 S 3358.17 W 0.00 3454.39 6000.00 25.00 256.44 4299.75 859.16 S 3563.59 W 0.00 3665.69 6500.00 25.00 256.44 4752.90 908.69 S 3769.01 W 0.00 3877.00 7000.00 25.00 256.44 5206.05 958.22 S 3974.43 W 0.00 4088.31 7500.00 25.00 256.44 5659.21 1007.75 S 4179.86 W 0.00 4299.62 7710.52 25.00 256.44 5850.00 1028.60 S 4266.35 W 0.00 4388.59 7910.52 25.00 256.44 6031.26 1048.41 S 4348.52 W 0.00 4473.12 TD - 3 1/2" Casing pt All data is in feet unless otherwise stated. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level) . Bottom hole distance is 4473.12 on azimuth 256.44 degrees from wellhead. Total Dogleg for wellpath is 102.02 degrees. Vertical section is from wellhead on azimuth 256.45 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Falls Creek Unit #1,FC-4 Falls Creek Field,Kenai Peninsula, Alaska e PROP08AL LI8TING Page 2 Your ref FC-4 Version#l Last revised , 11-Dec-2003 MD Comment Comments in wellpath -------------------- -------------------- TVD Rectangular Coords. -------------------------------------------------------------------------------------------------------- 250.00 250.00 0.00 N 0.00 E KOP 1837.77 1532.02 185.98 8 771.41 W EOB - 13 3/8" Casing Pt. 3339.22 2201.71 500.93 8 2077.80 W Begin Drop 4879.66 3284.37 748.18 8 3103.30 W EOD - 9 5/8" Casing pt 4979.66 3375.00 758.08 8 3144.39 W FC-4 Beluga B2 Tgt 10Dec03 7910.52 6031.26 1048.41 8 4348.52 W TD - 3 1/2 " Casing pt Top MD Top TVD Rectangular Coords. Casing positions in string 'A' Rectangular Coords. ------------------------------ ------------------------------ Bot MD Bot TVD -------------------------------------------------------------------------------------------------------- Casing 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1837.77 4879.66 7910.52 1532.02 3284.37 6031.26 185.988 748.188 1048.418 Target name Geographic Location Targets associated with this we11path ------------------------------------- ------------------------------------- T.V.D. 771.40W 3103.30W 4348.52W 1072.628 758.088 Rectangular Coordinates 4331. 03W 3144.39W 13 3/8" Casing 9 5/8" Casing 3 1/2" Casing Revised --------------------------------------------------------------------------------------------------------- FC-4 TD Tgt 10-Dec-0 235628.000,2268414.000,999.00 FC-4 Beluga B2 Tgt 1 236821.080,2268703.050,999.00 5850.00 3375.00 ll-Dec-2003 ll-Dec-2003 e e MARATHON Oil Company Falls Creek Unit #1 FC-4 slot #4 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-4 Version#l prop5585 Date printed Date created Last revised 11-Dec-2003 11-Dec-2003 11-Dec-2003 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 12 15.309,w151 25 45.491 Slot Grid coordinates are N 2269393.620, E 239980.900 Slot local coordinates are 1840.36 N 2829.48 W Projection type: NAD27 ASP ZONE 4 Reference North is True North e e MARATHON Oil Company PROP08AL LI8TING Page 1 Falls Creek Unit #1,FC~4 Your ref FC~4 Version#l Falls Creek Field,Kenai Peninsula, Alaska Last revised 11~Dec~2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D 8 Depth Degrees Degrees Depth C 0 0 R D I N A T E 8 Deg/lOOft 8ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 239980.90 2269393.62 250.00 0.00 0.00 250.00 O.OON O.OOE 0.00 0.00 239980.90 2269393.62 300.00 2.00 256.45 299.99 0.208 0.85W 4.00 0.87 239980.05 2269393.43 400.00 6.00 256.45 399.73 1.848 7.63W 4.00 7.85 239973.23 2269391.95 500.00 10.00 256.45 498.73 5.108 21.16W 4.00 21.76 239959.64 2269388.97 600.00 14 .00 256.45 596.53 9.978 41. 36W 4.00 42.55 239939.33 2269384.54 700.00 18.00 256.45 692.63 16.438 68.15W 4.00 70.11 239912.41 2269378.65 800.00 22.00 256.45 786.58 24.448 101. 40W 4.00 104.30 239879.01 2269371.35 900.00 26.00 256.45 877.92 33.988 140.93W 4.00 144.97 239839.28 2269362.67 1000.00 30.00 256.45 966.20 44.988 186.56W 4.00 191.90 239793.42 2269352.65 1100.00 34.00 256.45 1050.98 57.398 238.06W 4.00 244.89 239741. 67 2269341.34 1200.00 38.00 256.45 1131.87 71 .178 295.19W 4.00 303.65 239684.26 2269328.79 1300.00 42.00 256.45 1208.46 86.238 357.67W 4.00 367.92 239621. 47 2269315.07 1400.00 46.00 256.45 1280.38 102.518 425.19W 4.00 437.37 239553.63 2269300.24 1500.00 50.00 256.45 1347.28 119.928 497.42W 4.00 511.67 239481. 04 2269284.38 1600.00 54.00 256.45 1408.83 138.398 574.01W 4.00 590.45 239404.07 2269267.56 1700.00 58.00 256.45 1464.74 157.818 654.59W 4.00 673.34 239323.10 2269249.86 1800.00 62.00 256.45 1514.73 178.118 738.76W 4.00 759.93 239238.51 2269231.38 1837.77 63.51 256.45 1532.02 185.988 771.41W 4.00 793.51 239205.71 2269224.21 2000.00 63.51 256.45 1604.38 220.018 912.56W 0.00 938.70 239063.86 2269193.21 2500.00 63.51 256.45 1827.39 324.898 1347.60W 0.00 1386.21 238626.68 2269097.67 3000.00 63.51 256.45 2050.41 429.778 1782.65W 0.00 1833.72 238189.50 2269002.12 3339.22 63.51 256.45 2201.71 500.938 2077.80W 0.00 2137.33 237892.90 2268937.30 3400.00 61. 99 256.45 2229.53 513.608 2130.33W 2.50 2191. 37 237840.12 2268925.77 3500.00 59.49 256.45 2278.41 534.048 2215.13W 2.50 2278.60 237754.89 2268907.14 3600.00 56.99 256.45 2331. 04 553.978 2297.79W 2.50 2363.62 237671. 84 2268888.99 3700.00 54.49 256.45 2387.32 573.348 2378.13W 2.50 2446.27 237591.10 2268871.34 3800.00 51.99 256.45 2447.16 592.118 2456.01W 2.50 2526.38 237512.84 2268854.24 3900.00 49.49 256.45 2510.44 610.268 2531.27W 2.50 2603.80 237437.20 2268837.71 4000.00 46.99 256.44 2577.03 627.748 2603.79W 2.50 2678.39 237364.33 2268821.78 4100.00 44.49 256.44 2646.82 644.538 2673.41W 2.50 2750.00 237294.37 2268806.49 4200.00 41.99 256.44 2719.66 660.588 2740.00W 2.50 2818.50 237227.45 2268791.87 4300.00 39.49 256.44 2795.42 675.888 2803.44W 2.50 2883.76 237163.70 2268777.94 4400.00 36.99 256.44 2873.96 690.398 2863.61W 2.50 2945.66 237103.24 2268764.72 4500.00 34.49 256.44 2955.12 704.088 2920.39W 2.50 3004.07 237046.18 2268752.25 4600.00 31.99 256.44 3038.75 716.928 2973.68W 2.50 3058.88 236992.63 2268740.55 4700.00 29.49 256.44 3124.69 728.908 3023.37W 2.50 3109.99 236942.70 2268729.63 4800.00 26.99 256.44 3212.78 739.998 3069.36W 2.50 3157.31 236896 .47 2268719.53 4879.66 25.00 256.44 3284.37 748.188 3103.30W 2.50 3192.22 236862.37 2268712.08 4979.66 25.00 256.44 3375.00 758.088 3144.39W 0.00 3234.48 236821.08 2268703.05 5000.00 25.00 256.44 3393.44 760.108 3152.74W 0.00 3243.08 236812.68 2268701.22 5500.00 25.00 256.44 3846.59 809.638 3358.17W 0.00 3454.39 236606.25 2268656.10 6000.00 25.00 256.44 4299.75 859.168 3563.59W 0.00 3665.69 236399.82 2268610.98 6500.00 25.00 256.44 4752.90 908.698 3769.01W 0.00 3877.00 236193.39 2268565.86 7000.00 25.00 256.44 5206.05 958.228 3974.43W 0.00 4088.31 235986.96 2268520.74 7500.00 25.00 256.44 5659.21 1007.758 4179.86W 0.00 4299.62 235780.53 2268475.62 7710.52 25.00 256.44 5850.00 1028.608 4266.35W 0.00 4388.59 235693.61 2268456.62 7910.52 25.00 256.44 6031.26 1048.418 4348.52W 0.00 4473.12 235611.04 2268438.58 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level) Bottom hole distance is 4473.12 on azimuth 256.44 degrees from wellhead. Total Dogleg for wellpath is 102.02 degrees. Vertical section is from wellhead on azimuth 256.45 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e MARATHON Oil Company Falls Creek Unit #1,FC-4 Falls Creek Field,Kenai Peninsula, Alaska MD TVD Rectangular Coords. e PROP08AL LI8TING Page 2 Your ref FC-4 Version#l Last revised : 11-Dec-2003 Comment Comments in wellpath -------------------- -------------------- ~---------------------------------------------------------------------------------------------------------- 250.00 1837.77 3339.22 4879.66 7910.52 250.00 1532.02 2201.71 3284.37 6031.26 TOp MD Top TVD O.OON 185.988 500.938 748.188 1048.418 O.OOE 771.41W 2077.80W 3103.30W 4348.52W KOP EOB - 13 3/8" Casing Pt. Begin Drop EOD - 9 5/8" Casing pt TD - 3 1/2" Casing pt Rectangular Coords. Casing positions in string IAI Rectangular Coords. ------------------------------ ------------------------------ Bot MD Bot TVD ----------------------------------------------------------------------------------------------------------- Casing Target name 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1837.77 6639.86 7910.52 1532.02 4879.66 6031. 26 185.988 922.548 1048.418 Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location T.V.D. 771. 40W 3826.47W 4348.52W 1072.628 758.088 Rectangular Coordinates 4331.03W 3144.39W 13 3/8" Casing 9 5/8" Casing 3 1/2" Casing Revised ----------------------------------------------------------------------------------------------------------- 11-Dec-2003 ll-Dec-2003 FC-4 TD Tgt 10-Dec-0 235628.000,2268414.000,999.00 FC-4 Beluga B2 Tgt 1 236821.080,2268703.050,999.00 5850.00 3375.00 Wel! Co Field: Foils Creek Field location: Kenoi Peninsula, RKB(NQt!Q!"5 TRUE [\jORTH 20 330 30 320 40 10 50 .300 290 280 80 2 90 260 100 250 i 10 240 120 230 130 220 140 2îO 150 200 î60 90 î80 î70 Norma Plane Inder - Feet Ail shown Measured depths on Reference Well Creoted by bmiçhoei Dote plotted: 11-Dec--2003 Well il orn Piot VBrs¡on#1 Structure Fal!s Creek Unit #1 Location Kenai Peninsula, (Nobors Field: Falls Creek Field COQrdinol€s ore in feet reference slot #4 Vertical Depths ore INT£Q West (f eet) 840 800 750 720 580 540 600 550 520 480 440 400 350 320 280 240 200 i60 1400 ~ ~ ~ "1500 6~~ 1500 1.;3..00- - / ~ 2900 100 3000 2900 _~~ÔO ~ ~íOÕCl 120 80 40 o 900 300 ___ --'0)300 ~ ~6ÕO ~ -"700 _ -"soo 40 80 40 0 40 80 (j) 120 0 160 <D <D - ~ 200 240 280 5000 4800 Crected by brnichoel Dote p!Qtted ; 11-Dec-2003 Plo! Reference is FC-4 VGfsion# t il om a Structure Foils Creek Unit #1 Well FC-4 Field: Falls Creek Field Location Kenai Peninsula. Coordinates Ofe in IG€t referenC£1 slol #4 Vertical Depths ore ,derence RK8 (Nobors INTEQ <: - West (feet) 4600 4400 4200 3800 3400 3000 2800 2400 nOD 2600 4000 3600 3200 12900 2000 11400 0800 0200 2000 IBDO 1400 1600 2,100 5Î --"'- _ - 3000 _ _ - 3300 _ - ,-",900 ~ ~ "4500 ~ "5100 ~2700 -'5700 __ - --"' 1800 ~'2100 4200 1200 800 1000 3900 600 400 600 400 200 0 " 200 U) 400 0 !:: -i- :T 600 800 V 1000 1200 1600 e e MARATHON Oil Company Falls Creek Unit #1 FC-4 slot #4 Falls Creek Field Kenai Peninsula, Alaska 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License FC-4 Version#l prop5585 Date printed Date created Last revised ll-Dec-2003 ll-Dec-2003 ll-Dec-2003 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 12 15.309,w151 25 45.491 Slot Grid coordinates are N 2269393.620, E 239980.900 Slot local coordinates are 1840.36 N 2829.48 W Projection type: NAD27 ASP ZONE 4 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Last revised Distance 5-Feb-2002 64.1 7-Feb-2002 64.1 31-Jul-2003 20.8 Minimum Distance method M.D. Diverging from M.D. 530.0 530.0 530.0 5620.0 0.0 7910.5 MSS <0 - 13785> Dpth Shift"FC #l,Falls Creek PGMS <1095 - 8900>, ,FC #lRd,Falls Creek Unit # MWD <0-10668'>"FC-3,Falls Creek Unit #1 e e MARATHON Oil Company CLEARANCE LISTING Page 1 Falls Creek Unit #1,FC-4 Your ref FC-4 Version#l Falls Creek Field,Kenai Peninsula, Alaska Last revised : 11- Dec - 2 0 0 3 Reference wellpath Object wellpath MSS <0 - 13785> Dpth Shift"FC #l,Falls Creek Unit Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 o .ON O.OE 4.6 0.0 55.7N 42.0W 323.0 69.8 69.8 100.0 100.0 o .ON O.OE 104.6 100.0 55.7N 42.0W 323.0 69.8 69.8 200.0 200.0 o .ON O.OE 204.6 200.0 55.7N 42.0W 323.0 69.8 69.8 300.0 300.0 0.2S 0.8W 304.6 300.0 55.7N 42.1W 323.6 69.5* 69.5* 400.0 399.7 1. 8S 7.6W 404.3 399.7 55.7N 42.1W 329.1 67.1* 67.1* 500.0 498.7 5.1S 21. 2W 503.3 498.7 55.8N 42.2W 340.9 64.4* 64.4* 600.0 596.5 10.0S 41.4W 601.1 596 .5 55.8N 42.3W 359.2 65.8 65.9 700.0 692.6 16.4S 68.2W 697.2 692.6 55.8N 42.4W 19.6 76.7 77.9 800.0 786.6 24.4S 101. 4W 791.2 786.6 55.8N 42.5W 36.3 99.6 104.2 900.0 877.9 34.08 140.9W 882.6 878.0 55.9N 42.6W 47.6 133.2 144.8 1000.0 966.2 45.08 186.6W 971.0 966.4 55.9N 42.7W 55.0 175.7 199.3 1100.0 1051.0 57.48 238.1W 1055.8 1051. 2 56.0N 42.9W 59.9 225.7 268.4 1200.0 1131.9 71. 28 295.2W 1137.4 1132.8 56.1N 43.1W 63.2 282.4 353.3 13 00.0 1208.5 86.28 357.7W 1214.3 1209.7 56.3N 43.5W 65.6 345.0 452.9 1400.0 1280.4 102.58 425.2W 1287.9 1283.3 56.5N 44.0W 67.4 413 .1 557.1 1500.0 1347.3 119. 98 497.4W 1358.0 1353.4 56.4N 44.6W 68.7 486.0 661. 5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 256.45 degrees. Calculation uses the minimum curvature method. e Presented by Baker Hughes INTEQ MARATHON Oil Company Falls Creek Unit #1,FC-4 Falls Creek Field,Kenai Peninsula, Alaska Reference wellpath M.D. T.V.D. 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 966.2 1051.0 1131.9 1208.5 1280.4 1500.0 1347.3 0.0 100.0 200.0 300.0 399.7 498.7 596 .5 692.6 786.6 877.9 Rect Coordinates O.ON O.ON O.ON 0.28 1. 88 5.18 10.08 16.48 24.48 34.08 45.08 57.48 71.28 86.28 102.58 119.98 21. 2W 41.4W 68.2W 101.4W 140.9W 186.6W 238.1W 295.2W 357.7W 425.2W 497.4W Object wellpath O.OE O.OE O.OE 0.8W 7.6W 4.6 104.6 204.6 304.6 404.3 M.D. T.V.D. e CLEARANCE LI8TING Page 2 Your ref FC-4 Version#l Last revised : 11-Dec-2003 PGM8 <1095 - 8900>, ,FC #lRd,Falls Creek Unit Rect Coordinates 55.7N 55.7N 55.7N 55.7N 55.7N 55.8N 55.8N 55.8N 55.8N 55.9N 55.9N 56. ON 56.1N 56.3N 56.5N 56.4N 42.0W 42.0W 42.0W 42.1W 42.1W 42.2W 42.3W 42.4W 42.5W 42.6W 42.7W 42.9W 43.1W 43.5W 44. OW 44.6W Horiz Bearing 323.0 323.0 323.0 323.6 329.1 340.9 359.2 19.6 36.3 47.6 MinIm Dist TCyl Dist 69.8 69.8 69.8 69.5* 67.1* 69.8 69.8 69.8 69.5* 67.1* 503.3 601.1 697.2 791.2 882.6 971.0 1055.8 1137.4 1214.3 1287.9 1358.0 0.0 100.0 200.0 300.0 399.7 498.7 596.5 692.6 786.6 878.0 966.4 1051.2 1132.8 1209.7 1283.3 1353.4 64.4* 65.8 76.7 99.6 133.2 64.4* 65.9 77.9 104.2 144.8 55.0 59.9 63.2 65.6 67.4 199.3 268.4 353.3 452.9 557.1 175.7 225.7 282.4 345.0 413 .1 68.7 661. 5 486.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level) . Total Dogleg for wel1path is 0.00 degrees. Vertical section is from wellhead on azimuth 256.45 degrees. Calculation uses the minimum curvature method. tit e Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 3 Falls Creek Unit #1,FC-4 Your ref FC-4 Version#l Falls Creek Field,Kenai Peninsula I Alaska Last revised , ll-Dec-2003 Reference wellpath Object wellpath MWD <0-10668'>"FC-3,Falls Creek Unit #1 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 9.2 0.0 20.6N 3.3W 350.8 20.8 20.8 100.0 100.0 O.ON O.OE 109.2 100.0 20.6N 3.4W 350.7 20.9 20.9 200.0 200.0 O.ON O.OE 209.2 200.0 20.6N 3.3W 350.9 20.9 20.9 300.0 300.0 0.28 0.8W 309.1 299.9 21.3N 3.2W 353.7 21.6 21.6 400.0 399.7 1. 88 7.6W 408.6 399.4 22.0N 2.9W 11.2 24.3 24.3 500.0 498.7 5.18 21.2W 507.9 498.7 23.1N 3.0W 32.8 33.6 33.9 600.0 596.5 10.08 41. 4W 607.6 598.3 24.1N 6.0W 46.0 49.2 49.9 700.0 692.6 16.48 68.2W 709.2 699.5 24.5N 15.1W 52.4 67.4 68.6 800.0 786.6 24.48 101. 4W 812.7 801.7 23.4N 31.6W 55.6 86.0 87.4 900.0 877.9 34.08 140.9W 914.8 901.2 20.5N 53.7W 58.0 105.5 107.6 1000.0 966.2 45.08 186.6W 1020.0 1002.5 15.6N 81. 5W 60.1 126.6 129.4 1100.0 1051.0 57.48 238.1W 1126.2 1102.9 7.6N 115.4W 62.1 148.2 151. 6 1200.0 1131.9 71.28 295.2W 1234.4 1202.5 2.88 156.2W 63.8 170.3 174.0 1300.0 1208.5 86.28 357.7W 1347.5 13 03.0 15.68 206.5W 65.0 191.8 195.7 1400.0 1280.4 102.58 425.2W 1457.7 1396.8 28.78 262.8W 65.6 213.0 217.4 1500.0 1347.3 119.98 497.4W 1569.7 1487.8 41.78 326.7W 65.4 234.5 239.3 1600.0 1408.8 138.48 574.0W 1683.6 1575.4 54.28 398.5W 64.4 256.2 261. 8 1700.0 1464.7 157.88 654.6W 1804.9 1662.6 66.78 481.7W 62.2 278.1 283.3 1800.0 1514.7 178.18 738.8W 1913.7 1734.8 77.78 562.4W 60.3 299.3 307.8 1900.0 1559.8 199.08 825.5W 2006.5 1795.5 87.08 632.0W 59.9 324.9 337.5 2000.0 1604.4 220.08 912.6W 2101.2 1858.2 96.78 702.3W 59.6 352.0 365.5 2100.0 1649.0 241.08 999.6W 2198.8 1922.8 106.78 774.6W 59.2 379.0 392.5 2200.0 1693.6 262.08 1086.6W 2305.8 1993.1 118.78 854.6W 58.3 405.0 416.5 2300.0 1738.2 282.98 1173.6W 2414.0 2061.9 132.88 936.7W 57.6 428.3 438.7 2400.0 1782.8 303.98 1260.6W 2510.5 2122.1 145.68 1011.1W 57.6 449.9 461.4 2500.0 1827.4 324.98 1347.6W 2608.5 2183.6 158.58 1086.3W 57.5 472 .1 482.1 2600.0 1872.0 345.98 1434.6W 2718.0 2251.1 174.98 1171. OW 57.0 492.3 502.3 5000.0 3393.4 760.18 3152.7W 5039.5 3727.9 498.28 2932.1W 40.1 478.7* 523.3 5100.0 3484.1 770.08 3193.8W 5126.2 3783.0 512.88 2997.5W 37.4 440.5* 478.4* 5200.0 3574.7 779.98 3234.9W 5212 .0 3838.2 527.78 3061. 5W 34.5 403.9* 435.2* 5300.0 3665.3 789.88 3276.0W 5300.4 3896.0 542.68 3126.7W 31.1 369.6* 394.4* 5400.0 3756.0 799.78 3317.1W 5389.9 3954.5 556.98 3192.8W 27.1 337.4* 356.7* 5500.0 3846.6 809.68 3358.2W 5479.6 4012.7 569.98 3259.8W 22.3 307.8* 322.2* 5600.0 3937.2 819.58 3399.3W 5566.6 4068.9 581.28 3325.4W 17.2 282.1* 291. 5* 5700.0 4027.9 829.48 3440.3W 5658.0 4127.8 592.48 3394.3W 11.0 261. 3 * 266.6* 5800.0 4118.5 839.38 3481. 4W 5747.0 4185.6 603.58 3461.0W 4.9 246.0* 248.1* 5900.0 4209.1 849.38 3522.5W 5835.5 4242.6 613.98 3527.8W 358.7 237.8* 238.1* 6000.0 4299.7 859.28 3563.6W 5924.3 4299.3 623 .28 3595.7W 352.3 238.1 238.4 6100.0 4390.4 869.18 3604.7W 6017.6 4359.4 633.28 3666.3W 345.3 245.7 247.3 6200.0 4481.0 879.08 3645.8W 6108.8 4418.4 643.78 3735.0W 339.2 259.3 263.7 6300.0 4571.6 888.98 3686.8W 6194.6 4473.8 653.38 3799.9W 334.4 279.0 289.2 6400.0 4662.3 898.88 3727.9W 6278.6 4526.0 661.98 3865.1W 329.9 305.8 322.3 6500.0 4752.9 908.78 3769.0W 6368.1 4581.3 670.58 3934.9W 325.1 337.2 358.8 6600.0 4843.5 918.68 3810.1W 6461.8 4639.4 679.98 4007.9W 320.3 371.2 397.1 6700.0 4934.2 928.58 3851. 2W 6553.6 4696.4 690.48 4079.0W 316.3 406.3 437.2 6800.0 5024.8 938.48 3892.3W 6643.0 4752.3 700.78 4148.1W 312.9 442.9 475.6 6900.0 5115.4 948.38 3933.3W 6746.1 4817.2 713.48 4227.2W 308.6 480.1 510.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4 and TVD from RKB (Nabors 129) (261.40 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 256.45 degrees. Calculation uses the minimum curvature method. Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Prepared M RATHON OIL COMPANY Well Falls Creek Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Hal Martins Presented to: David CastiHo December 11, 2003 e e Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: David Castillo David: Enclosed is the revised recommended drilling fluid program for the Falls Creek #4 Well to be drilled next year. The following is a brief synopsis of the program. Overview: FC #4 is a development well targeting the Beluga and Tyonek formations at the Falls Creek field. A Gel/Gel ex spud mud is recommended for the surface interval. Flo- Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 3 1/2" liner cemented in place. Surface Interval: A standard fresh water Gel/Gelex spud mud will be used. Initial funnel viscosity should be in the 50 -75 sec/qt range. Lower funnel viscosity to 45 - 60 sec/qt after gravel has been drilled. Lower fluid loss to < 10 cc's API prior to running surface casing. Potential fluid losses to the formation may be controlled by additions of G-Seal and/or sized calcium carbonate. G-Seal can also reduce torque in the build area of the surface hole. Intermediate Interval: This interval will be drilled with a Flo-Pro fluid. After drilling out the surface cement, the well will be displaced to a standard Flo-Pro KCl fluid. Safecarb bridging material will be maintained according to the mud program to minimize losses to the formation. Production Interval: This interval will be drilled with Flo-Pro fluid. After drilling out the intermediate cement and 20 - 25 feet of new hole, the well will be displaced to a new Flo-Pro KCl fluid. Fluid loss should be maintained @ < 6 cc's API for this interval. Gas encountered may require the mud weight to be increased to +/- 10.0 ppg. Completion: This program assumes the well will be completed with 6% KCl brine. Tony Tykalsky Project Engineer M - I Drilling Fluids Reference Wells: Falls Creek #1 RD, Falls Creek #3 NOTE: This pr02ram is provided as a 2uide only. Well conditions will always dictate fluid properties reQuired. r:zj ..FE ~ - .IFE m ~ ..... IÆ e e Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. EXECUTIVE SUMMARY Our overall goal is no M-I/Swaco HSE incidents while providing fluids and solids control services to our customer. Our goal for CLU #8 is to remove drill solids from the mud system at a cost of less than $0.23 per pound. This has been the average for the last three years of centrifuge van operations With the revised fluid formulation (increasing the fluid agent concentration and maintaining a lower fluid loss), we expect to minimize formation damage and hole enlargement in the production interval as demonstrated on KBU 43-7X. Use of the MI Swaco centrifuge van for the last three years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $500,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. ~ ..FE ~~ -- e - ;&t IFE Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth Benchmark 1 Benchmark 2 Benchmark 3 Benchmark 4 Interval (ft) Fluid cost per foot Volume Usage Solids Removal 0-1837' > $6.44 ft < 1770 bb1s 1837 - 4879' > $53.89 ft < 2669 bb1s 4879 - 7910' > $29.11 ft < 1502 bb1s Total Project Avg. Max. Targets for < $33.37 < 5941 bb1s < $0.23 1b No Spills from Centrifuge Drilling Van Operation Interval r:zj SIÆ ~~ Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Gelex Mud Screens 150/180 mesh DesHter Centrifuge Van 3284' 9.0-9.6 10 w/SafeCarb Screens 180 210 mesh Desilter Centrifuge Van 3-1/2" 8-1/2" 7910' 6031 ' FIo-Pro 9.0 9.6 7 w/S afeC arb Screens 230 - 210 mesh Desilter Centrifuge Van 3 1/2" 8-1/2" Completion 7910' 6031' 6% KCl y Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). y Condition the mud prior to running casing for all intervals. y Cost does not include any considerations for whole mud losses. y Cost includes 1 % Lubetex concentration for intermediate and production interval. e e IFE Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Product Usage Summary M-I Bar 0 133 225 0 358 1. M-I Gel 398 0 0 0 398 2.1 Gelex 22 0 0 0 22 0.1 Soda Ash 12 13 8 0 33 0.2 Caustic Soda 18 27 15 0 60 .6 Conqor 404 0 6 5 0 11 4.7 SafeScav NA 4 6 3 0 13 1.8 Bicarb 18 13 15 0 46 0.3 Conqor 303 0 0 0 6 6 .9 FloVis 0 240 120 3 363 26.4 Desco CF 10 0 0 0 10 .5 DualFlo 0 0 180 0 180 5.5 Polypac UL 18 107 0 0 125 7.3 Greencide 25G 0 0 2 0 2 1 Bioban BP Plus 0 213 120 0 333 2.7 KCI 0 1121 631 273 2025 9.4 Safecarb 0 1067 601 0 1668 10.8 SafeKleen 0 1 1 1 3 .4 Lubetex 0 31 17 0 48 13.0 Defoam X 0 30 17 0 47 1.5 Klagard 0 23 0 0 23 5.9 Engineer Service 5 10 7 2 24 r:zj _.FE m!?~ e e ~IFE Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Offset Well Information Well Hole Size Depth PPG PV YP FL Comments FC #1 RD 6.75 3307 8.9 6 24 7.8 Drill out, displace hole to new fluid 3542 9.1 9 28 6.2 Rig down to one pump - increase LSRV 4127 9.3 10 27 6.4 Drlg ahead 4753 9.15 9 31 5.6 Short trip - OK 5124 9.3 10 30 5.8 Drlg ahead 5675 9.4 10 26 6.8 5875 9.25 10 30 7.0 Trip out - OK Test BOP's 6510 9.35 10 28 7.0 Drlg ahead 6803 9.4 10 24 6.9 Trip for bit 7250 9.28 10 21 7.1 Drlg ahead 7683 9.25 9 21 7.5 7930 9.3 9 21 6.9 Short trip - very good 8635 9.2 9 19 7.2 Drlg ahead 8903 9.25 10 20 8.0 Drlg to T.D. trip - OK FC#3 16 1481 8.9 16 36 14 Spud in, drlg ahead 1960 9.3 10 35 11 10' fill at wiper trip 12.25 2883 9.3 14 39 6.8 New mud, drlg out & drlg ahead 3727 9.6 12 41 7.8 Drlg ahead, lots of clays 4730 9.85 15 25 6.4 Lots of clay, dump & dilute as needed 5397 9.95 16 28 9.4 Trip for new bit, drlg ahead 5854 10 13 33 10.4 Short trip tight & backream, drlg ahead 6737 9.8 12 26 9.8 Drlg ahead, dump & dilute as needed for clays 7719 9.75 12 32 5.2 Drlg ahead, d&d, reduce ppg & fluid loss 8010 9.75 16 22 5.8 Log hole & dilute with new mud 6.125 8234 9.2 11 19 4.5 Drlg out with new mud 9025 9.3 13 24 4 Drlg ahead no problems 9987 9.3 13 34 4 Short trip, ok 10668 9.55 12 31 3.6 Lost some fluid to formation, add safecarb 10668 9.4 10 29 4.5 Log hole, run liner & cement r:zj ..FE ~~ e e -..... ~IFE Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterlng A8 Sands - Refer to fluid fonnulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intennediate and production intervals. => FLUID LOSS CONTROL - In the intennediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained at less than 6 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. It is particularly important to maintain a low hardness «200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If additions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained around 40,000 cps. In addition to adequate additions of Flo Vis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSR V. => DRILL SOLIDS - MBT - The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCl should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRISION - SafeScav NA additions should be made daily as needed with any fluid in the hole. Maintain a DO reading ofless than 3 ppm => GREENCIDE 25G ADDITIONS - Greencide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un-acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the detennining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. p:j ..FE ~~ e e AIFE -- Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Interval Summary -16" hole o - 1837 .... Drilling Fluid System Gel/Gelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions ~nterval Drilling Fluid Properties ... Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec./qt) (lb./1OOft2) (mIl30min) (%) 0-1837' 8.6 - 9.4 60 - 100 25 - 35 NC - 12 +/- 9.5 <7% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. ~ Lower funnel viscosity to +/- 75 after gravel zone has been drilled. ~ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions ofPolypac Supreme UL prior to running surface casing. ~ Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval- 1770 barrels. ~ Estimated haul off volume - 3654 barrels. ~ fa.FE ~~ e e - ~IFE Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Interval Summary - 12-1/4" hole 1837 - 4879' Drilling Fluid System Flo- Pro Fluid Key Products Flo- Vis / PolyPac UL / KCI / SafeCarb F & M, Asphasol Supreme / tLubetex / KlaGard / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) (cp.) (cps) (mIl30min) (%) 1837 - 4879' 9.0- 9.6 8 -12 40,000 8 - 10 +/- 9.5 +/- 7.5 % >- Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. >- After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak offtest. >- Maintain DO reading of less than 3 ppm with additions of SaveScav NA. >- Maintain Conqor 404 concentration of 2000+ ppm. >- If running coals become a problem, increase Asphasol Supreme additions. >- Estimated volume usage for interval - 2669 barrels. >- Estimated haul off volume - 3547 barrels. >- Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~.IFE ~ Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. No 6 11 Reduce BHA Ballin 12 Lubricit 2669 Barrels e e Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole 4879 -7910' Drilling Fluid System Flo- Pro Fluid Key Products Flo-Vis / DualFlo / KCI/ Greencide 25G / SafeCarb F, KlaGard / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties i . Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) ( cpo ) (cps) (ml/30min) (%) 4879 - 7910' 9.0-9.6 10 - 14 40,000 <6 +/- 9.5 +/- 5% ~ Use one rig pit for drilling out intermediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. ~ If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. ~ Periodic additions of Greencide 25G will be needed to control bacteria build-up. ~ Estimated volume usage for interval- 1502 barrels. ~ Estimated haul off volume - 2458 barrels. ~ Condition mud prior to running 3-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. rnJIIIÆ ~~ Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, - Falls Creek #4 9.05 SafeCarb 2.8 0.35 No No 6 0.2516 325.19 2 0.10 3 0.84 4 4.00 bA 5.30 5B 2.30 6 8.68 7 0.30 8 1.43 9 0.23 10 0.25 11 4.00 12 7.00 13 1.33 380.1 9.050 29600 No Reduce BHA Ballin Wellbore Stabilit e e Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. HSE Issues HANDLING OF DRilLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office ofthe Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. ~ ..FE ~~ Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Product M-I BAR M-I GEL GELEX FLOVIS DUAL-FLO POLYPAC XCD HEC Safe-Carb F,M,C LO WATE Nut Plug M-I Seal F, M, C Mix II F,M,C DESCO CF SPERSENE CF TANNATHIN VENTROL 401 SALT (Solar) BROMIDE (NaBr) & Brine Solution POTASSIUM CHLORIDE - Function Weighting Agent Viscosity control Bentonite Extender Viscosifier Modified Starch Fluid Loss Reducer Viscosifyer Loss Circulation Material Bridging and weighting agent Weighting agent Loss Circulation Mate Loss circulation Materi Loss circulation Materi Dispersant Dispersant Dispersant Surfactant Densifier Densifier Shale Inhibitor Marathon Oil Company Well Name: Falls Creek#4 Location: Kenai, Alaska. Product CAUSTIC SODA AUSTIC POTASH BORAX SAPP SODA ASH ODIUM BICARBONATE CITRIC ACID BIOBAN BP-PLUS GREEN CIDE 25G - DEFOAM X - D-D CWT Concor 404 SAFEKLEEN sphasolD Soltex SafeScav NA Function Ikalinity control pH Modifier norganic Borate rophosphate izedgraphite LCM ubricant Detergent Corrosion Inhibitor Drilling fluid additive ale Inhibitor e e Marathon Oil Company Well Name: Falls Creek #4 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions ~.IFE ~ Marathon Oil Company Well Name: Falls Creek#4 Location: Kenai, Alaska. 411 M1 Project Engineer and Tech Service Engineer will coordinate between the Marathon office, warehouse, and the M -I field engineers. .. Well progress will be monitored to look for any changes, which will improve operation or avert trouble. Project Team Craig Bieber Deen Bryan Title Home 907345-1239 District Manager Tony Tykalsky Gu.s Wik Tech Service 907373-2713 907223-1634 Project Engineer 907376-4613 907227-2412 Warehou.se Manager 907776-8722 907776..8680 . . Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 18, 2003 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Ave, Suite 100 Anchorage, AK 99501 Reference: Permit to Drill Application Field: Kenai Gas Field Well: Falls Creek 4 Dear Ms. Palin, Enclosed please find a PERMIT TO DRILL application, along with the associated attachments for the Falls Creek 4. Please note that Marathon is requesting a waiver for 20 ACC 25.035 (e) (1) (b) requiring a two pipe ram stack. The requests are specified on page 9 of the attached drilling ./ prognosis. A Location Exception Application is required and was applied for separately on / December 15, 2003. If you require further information, please contact me. Sincerely, ~R.~ David R. Castillo Senior Drilling Engineer RECE\VED DEC 1 B 2003 A\as\(a Oi\ & Gas Cons. commission Anchorage Telephone: 907-564-6465 Email: DRCastillo@MarathonOil.com nDlr!~\L~L . . Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Marathon Oil Company (MaC) for a spacing exception to allow the drilling and production of the Falls Creek No. 4 Gas Development Well in accordance with 20 MC 25.055. MaC by letter dated December 15, 2003 and received by the Alaska Oil and Gas Conservation Commission (Commission) on December 15, 2003, has requested the Commission to issue an order in conformance with 20 AAC 25.055 allowing regular production of the Falls Creek No.4 Gas Development Well from a location within the same governmental section and within 3000 feet of another well capable of producing from the same pool. The surface location of the proposed well is 2842 feet from the east line and 1842 feet from the south line of Section 6, T1 N, R12W Seward Meridian (SM). The proposed bottomhole location is 1910 feet from the east line and 794 feet from the south line of Section 1, T1N, R13W, S.M The Commission has tentatively set a public hearing on this application for January 22, 2004 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on January 9, 2004. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on January 22, 2004. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1230 no later than January 5, 20~. s~ Alaska Oil and Gas Conservation Commission Published December 22, 2003 ADN: AO-02414015 OGCC100.00 1107003 12/18/2003 NCBAS 7780 ··....î6@iWþ~i~.þi'Ì~µm~@.·~~. 12/18/2003 1900035472 Marathon Oil Company P. O. Box 3128 Houston, TX 77253 ~~~~uINí'šir~A Y~~LE DEPARTMENT Accts Payable - Customer Serv Phone: 713-296-4336 Hndlg Check No Check Date Bank Bank No Vendor N Al OTAl: 100.00 100.00 .@¥i~~&W.i@@M> . 100.0 100.0 CE\ EO DEC 1 '2.û03 . comm\SS\()~ nS. t8\}e Q'\ & Gas A ~a$¥.a" ¡. t\ þ.ntll (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) III 0 0 0 ¡. ¡. 0 7 0 0 :¡ III I: 0 L. ¡. 2 0 :¡ B g 5 I: 0 ¡. B :¡ L. B L.III e . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRJATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for wen (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. DRY DITCH An dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\jody\templates Field & Pool FALLS CREEK, TYONEK UNDEF GAS - 240500 Well Name: FALLS CREEK 4 Program DEV Well bore seg D PTD#:2032210 Company MARATHON OIL CO Initial ClasslType DEV /1-GAS GeoArea Unit On/Off Shore On Annular Disposal D Administration 1 P~rmitfee attache_d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leas~numberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nique weltn_a!TI~_aod (1~mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJlJocat~d ina d_efil1e_d _pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _No _ _ _ falls Çre~1s Tyo_nek unpef[ned _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJlJocat~d proper _distaoçe_ from driJling ul1itb_oUl1d_ary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WeUJocat~d proper distance_ from otbe.r wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Spacing e¡çceptioo applied tor 12122_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_u{ficiel1tacreag.e_ayailable ind.rilli(1g unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ l-ieaJiog (1otice in w~lJfiJe_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtd~viated, js weJlbore platJl1cJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Operator ol1ly affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Operator bas_apprppriateJ).ond inJQrce. _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P~rmit cao be iss~ed witbout COMervaJiOI1 order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ se_e _abov~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 P~rmitc_an be iss~ep witbout admil1istratille_apprpvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 12/19/2003 13 Can permit be approved before 15-day wait No 14 We.llJocat~d withil1 area al1d_strata _authorized by_lnjectio(1 Ord_er # (puUO# in_cpmm_ents) (For_ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJI WeIlSJNit.hirUl4J1.1ile_are.a_of reyieW id~ntified (Fpr servjc.e."Il.ell ol1lYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produced injector; purationof pre-propuctiOIJ I~ss t.hal13 mOlJtbs_ (For_serYice well onJy) _ _ _NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMP_F]l1djngof Consi,Steoçy_h_as beenissuedJorJbis project _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 18 _C9ndu_ctor stril1g_p.rovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urfac.e_casil1gpJotectsa(!_known_ USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTvoladeQuateJocirc_utateonCOlJductor_&suJfcsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s_ _ _ _ _ _ _Ade.quateexcess, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ ,21 _CMT v_oLadeQuateJo ti~-l'1Jong _striog to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22CMT will coyer.aU klJovyn.productiye borilon_s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 Casing de_sigos adequate.Jor C,J:, B_&perrnafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _Mequatetankage_oJ re_seTYe pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Nabors 129._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-prill~ has a 10c4.03 for abandOl1ment be~n apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ New well, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _Mequatewellbore.separationproposep_ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdivecteneq_uired, does itmeet reguJatiolJs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28DJiUiog fJuid_prog.ram schematic_& ect-uipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ Max MW9~6 ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WGA 12/22/2003 29 _B.oPEs, do they meetreguJatiolJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30B.oPEWe.ss ra_ting appropriate; test to (put psig in _comm(:!I]tsL _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Te.st to _3000_ ps[.MSfl2395 psi._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _CMkernanifold compJies w/APt RF'-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur withoytoperatjonshutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js presence of H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecba_nlcaLcOlJdition pf we.lIs withilJ J\OR yerified (for_ s_ervice welJ onJy) _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ e - Appr RPC 35 36 Date 37 12/19/2003 38 39 _Permit cao be iss~ed w!o_ hydrogen sulfide meaSjJres _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _D_atapJeselJted 011 pote_ntial pverpres_sure _ZOl1es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ S~ismlc_analysjs of sbaJlow gas_zo(1es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S~abed _col1ditip(1 survey (if ot(-sh9re) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Contact l1amelp.hol1eJor_weelsly progress_reports [exploratory _ooly] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date /¿Æe~ Db J <"'(2 'L / J e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · MARA THON OIL COMPANY FALLS CREEK #4 ~()]- ~~\ KENAI GAS FIELD KENAI BOROUGH, ALASKA FINAL WELL REPORT · February 9, 2004 Brian O'Fallon - Senior Logging Geologist Dick Ebright - Logging Geologist ~ EPOCH · · · · (.M)Marathon Oil Company - Falls Creek #4 TABLE OF CONTENTS WELL RESU ME..... ............................... .... ................... .... ........ ......... ........ .... ....... ....... ....3 GEOLOGICAL DISCUSSION .............. .... ... ....... ... ............ ........... ...... ... ....... ................ 11I..5 LITHOLOGY AND COM MENTS ......... ............. ..... ........ ...... ...... ............................. ......... 8 SU RVEY INFORMATION................ ...... ............. ..................... ...................................... 18 DAILY MU D PROPERTIES..·.. ...... ................ ......... III III..... ...... ..... II. II II.. ............. .......... ..... II ... 20 BIT RECORD ............................. ..... ... ......... ................. ...... ......... ..................... ............. 21 MORN I NG REp·ORTS................................................................................................... 22 ~ EPOCH 2 · · · (.M)Marathon Oil Company - Falls Creek #4 WELL RESUME Company: Marathon Oil Company Well: Falls Creek #4 Field: Ninilchik UniUFalls Creek Region: Kenai Peninsula Location: 1842'FSL & 2842'FEL SEC.6-T1N-R12W X=239981 Y=2269394 KB 261.5'/ GL 245' Coordinates: Elevation: County, State: Kenai Borough, Alaska API Index: 50-133-205-3300 01/20/2004 7910' Spud Date: Total Depth: Contractor: Nabors Alaska Drilling Company Representative: Gene Anderson Rowland Lawson RigfType: Nabors #129/ Land Epoch Logging Unit: ML#30 Epoch Personnel: Brian 0' Fallon Dick Ebright James Longley Sergei Pokrovski Company Geologist: David Brimberry, Bob Lanz g EPOCH 3 . . . Casing Data: Hole size: Mud Type: Logged Interval: Electric Logging Co: (.!!)Marathon Oil Company - Falls Creek #4 20" Conductor at 101' 13 3/8" landed at 1840' 9 5/8" landed at 4889' 16" to 1860' 12 1/4" to 4900' 81/2" to 7910" Gel Spud to 1860' FloPro to 7910' Monitor Gas 101' to 1860' Full Logging 1860' to 7910' Reeves U EPOCH 4 (.M)Marathon Oil Company - Falls Creek #4 · GEOLOGICAL DISCUSSION Marathon Oil Company spudded the Falls Creek #4 well on January 20, 2003 with Nabors Alaska Rig #129. Drilling progressed well with no significant rig delays to a total depth of 7910 feet reached on February 4, 2004. The primary objectives of this well were well developed sands of the Tyonek formation of the Tertiary Kenai Group Epoch Well Services provided RIGWA TCH 2000TM Drilling Monitoring services and DML TM Mudlogging Service. Hydrogen flame ionization (FID) Total Gas and (FID) Gas Chromatograph detectors were employed to detect and analyze formation gases. Gas was generated by Texaco's patented Quantitative Gas Measurement (QGMTM) electrically driven gas trap. The gas detector was located at the shale shaker header box (possum belly) and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 20' intervals, due to fast drilling, as directed · by Marathon Oil Company's sampling program. Several significant gas shows were encountered in the lower Beluga and Tyonek Sands. · g EPOCH 5 (.M.)Marathon Oil Company - Falls Creek #4 · CAlLY ACTIVITY SUMMARY 01/20/04: Epoch logged on 4:07 hours at 101', base of conductor pipe, after spud well (tagged at 26' and began drilling 2:30 hours). Drill to 128' with new bit no. 1, mud motor, and 4" DP. Changed BHA to include MWD tool and drilled to 200', kick off point. Worked on top drive, then drilled, mostly sliding, from 200' to 550'. 01/21/04: Drill from 550' to 1016', circulate hole clean and back ream out of hole. Change BHA to include 5" HWDP on trip in, and finish trip in with 4" DP. Wash to bottom on last stand, trip gas 9 units, and drill ahead, mostly sliding from 550' to 1267'. 01/22/04: Drill ahead, mostly sliding, from 1267' to 1860', casing depth, and circulating to clean hole. 01/23/04: Continue circulating until hole clean, gas to 14 units, and trip out of hole without problems. Check bit, and trip to bottom, working through bridge or ledge at 1550'. Circulate hole clean, gas to 7 units with maximum 20 units of trip gas. Trip out of hole, lay down BHA, and rig up and run 133/8" casing to bottom. Rig down after casing run and rig up to run inner string, 4" DP, for cement. 01/24/04: Finish running inner string of 4" DP inside 13 3/8" casing, circulate and clean hole and treat mud prior to cement casing, maximum 12 units of gas down to 3 units before cement. Cement casing, 1 unit of gas before cement returns at surface. Wait on cement 8 hours and nipple down hydril and diverter system and begin nipple up BOPs. 01/25/04: Finish nipple up BOPs while building 700 barrels mud volume (FloPro) in pits, and testing BOPs. No circulating past 24 hours.. · 01/26/04: Finish testing BOPs, test Casing, work on motor on drill floor, pick up 45 joints of drill pipe, and lay back 15 stands in derrick. Pick up BHA, run in hole with singles, tag cement at 1793', and drill to 1880'. Circulate hole clean and run leak off test, 18.0 ppg EMW. Drill ahead, rotating and sliding, from 1880' to 1939'. 01/27/04: Drill from 1939' to 2895', mostly rotating, circulate hole clean, and wiper trip to 13 3/8" casing shoe, backreaming out of hole due to numerous tight spots. Trip in and wash to bottom on last stand, 113 units of trip gas, and drill ahead, rotating, from 2895' to 2989'. 01/28/04: Drill from 2989' to 3947', rotating to 3485', and sliding and rotating to drop angle from 3485' to 3947'. Wiper trip to shoe, backreaming due to multiple tight spots. Tripping in hole. 01/29/04: Finish tripping in hole and wash down last stand, 109 units oftrip gas. Drill ahead, rotating and sliding, from 3946' to 4900', 9 5/8" casing depth. Circulating bottoms up at casing depth. 01/30/04: Circulate hole clean at least 4 bottoms up at casing depth. Pull out of hole 16 stands to 3373', backreaming 4 through 11 due to tight spots. Trip to bottom and circulate hole clean for 2 hours, 215 units of trip gas down to 35 units before pumps off. Trip out of hole, lay down BHA, change rams and pull wear ring, and rig up and begin to run 95/8" casing. 01/31/04: Run total 117 joints of 9 5/8" casing and hangar down to 4888 feet, and circulate bottoms up, maximum 75 units oftrip gas. Rig up and cement casing, maximum 26 units of gas down to 18 units after cement. Work on top drive and nipple up BOPs while dumping mud and cleaning pits. Rig up to begin testing BOPs and begin mixing mud. · g EPOCH 6 · · · (M)Marathon Oil Company - Falls Creek #4 02101/04: Continue mixing mud, and finish testing BOPs, pick up 90 joints of drill pipe, and stand back 30 stands in derrick. Test Casing, pick up BHA, and trip in hole to tag cement @ 4796'. Drill cement, float and shoe and 20' of formation down to 4920'. Perform formation integrity test, 17.2 ppg EMW, displace hole with new mud, and begin to drill ahead at midnight. 02/02104: Drill, mostly rotating, from 4920' to 5957', circulate two bottoms up and trip out to shoe, backreaming last two stands due tight spots. Cut and slip drill line and work on top drive. Trip to bottom washing down last stand, 315 units of trip gas. Drill ahead, mostly rotating, from 5957' to 6177'. 02/03/04: Drill from 6177' to 6913', wiper trip to 5856' with no problems, wash final stand to bottom, 245 units oftrip gas, and drill ahead, rotating and sliding, 6913' to 7131'. 02104/04: Drill ahead, rotating and sliding, from 7131' to 7606', and work on #2 pump. Drill ahead, rotating and sliding, from 7606' to 7910', total depth. Circulate two hours rotating 120 rpm to clean hole, and short trip to 6818', backreaming through tight spots. Trip to bottom and circulate two hours rotating 120 rpm to clean hole. Tripping out to shoe, some backreaming above 6818' due to tight spots. 02105/04: Finish tripping out to shoe at 4888', backreaming, and circulate one hour rotating 120 rpm to clean casing. Pull out of hole, lay down BHA, and rig up Reeves for wireline logging. Complete wireline logging without problems, rig down Reeves, and trip in hole. Circulate to clean hole for escape completion, 90 minutes rotating 90 rpm, 308 units of trip gas, and 90 minutes (until 1 am) rotating 80 rpm, gas to 17 units. 02106/04: Finish cleaning hole, pull out to shoe, and wait on orders (9 hours). Run to bottom and circulate hole clean rotating 95 rpm, maximum 106 units trip gas. Pull out of hole to shoe. Pump slug and pull out of casing and lay down 114 joints of drill pipe. 02/07/04: Run in hole with the 33 stands drill pipe remaining in derrick, and pull out and lay down remaining 114 joints of drill pipe. Lay down HWDP and bit, and rig up to run 3.5" excape completion. Run in hole with 3.5" tubing and all nine completion modules and the tank module. At 69 joints of tubing and 2650' at midnight. 02108/04: Finish running excape completion, 235 joints to 7863', and circulate hole clean, maximum 128 units of trip gas. Rig up and run wireline log, rig down wireline, and reposition excape completion tubing per wireline results. Circulate and condition hole, 45 units maximum gas, rig up for cement, test lines, and complete cement job after midnight. 02109/04: Epoch released after cement excape production tubing to rig down. g EPOCH 7 (.M)Marathon Oil Company - Falls Creek #4 · LITHOLOGY AND COMMENTS Sandstone (1860-1910') = light gray, fine to occasionally medium grain, mostly angular to some sub rounded, poorly sorted, poor sphericity, occasional rounded, spherical grains, trace very angular, bit shattered conglomerate pebbles, sand is composed of 70% clear to opaque to gray quartz, 30% dark gray to black mineral clasts, trace green chlorite stained chert, common dark gray aphanitic igneous rock fragments; estimate mostly slight ashy clay matrix to streaks sandy tuffaceous white to light gray siltstone; estimate poor clay infill to some fair to good porosity and permeability; no oil indicators. Conglomeratic Sand/Sand (1910-2040') = medium gray overall; fine upper to coarse grains and scattered to locally common very coarse grains, coarse fragments, and pebbles; angular to subangular and minor fraction sub-rounded to rare rounded; moderate sphericity; poorly sorted and estimate grain and matrix supported in silty ashy white to light gray clay matrix; 60% quartz, and 40% black to dark gray to opaque to gray to green to red to minor other including chert, aphanitic igneous mafics and volcanics, and partially siliceous lithics; estimate poor clay infill to some fair porosity and permeability; no oil indicators. Tuffaceous Claystone/Siltstone (1910-2100') = medium light gray to light greenish gray to very light gray; soft and soluble to slightly firm; smooth to silty texture; some sandy especially siltstone; occasionally conglomeratic; some with slight disseminated organic matter to slight carbonaceous partings and trace coal streaks to locally thinly interbedded coal; non calcareous. · Sand/Conglomeratic Sand (2040-2175') = medium gray to medium light gray; fine upper to medium and scattered coarse to very coarse grains and fragments to trace pebble; subangular to angular with occasional rounded to subrounded in coarser fraction; poorly to moderately sorted and estimate grain and matrix supported in ashy to slightly silty ashy light gray clay; 60% quartz, and 40% dark gray to black to green to opaque to rust including mostly igneous mafics chert, micas, and partially siliceous lithics; some sandstone with yellow brown firm clay matrix; estimate mostly poor clay infill to some fair porosity and permeability; no oil indicators. · Coal (2140-2250') = grayish black to brownish black; slightly firm and crumbly to firm and brittle; dense with hackly to planar fracture to laminated and flaky; lignite grading to carbonaceous shale; some grading subbituminous in lower coal; massive to thinly bedded to thinly interlaminated in carbonaceous shale. Tuffaceous Siltstone/Claystone (2160'-2300') = medium gray to medium light gray, some with greenish hue, to brownish gray; soft and soluble to slightly firm; silty to smooth texture; some sandy grading matrix supported fine grained sandstone; some interbedded coarser sandstone; some slightly organic locally grading carbonaceous shale with slight finely disseminated carbonaceous matter; trace micas and possible micro pyrite; mostly non calcareous to occasionally calcareous. Sandstone/Sand (2300-2400') = medium light gray to medium gray; fine to coarse lower, especially fine upper to medium grains; subangular to subrounded; moderate to high sphericity; moderately to some poorly sorted; grain and matrix supported in light gray to white ashy clay matrix; 70% quartz, and 30% gray to green to black to rust including chert, igneous, and partially siliceous carbonaceous to chloritic to clay lithics and trace micas; estimate poor to fair mostly clay infill porosity; no oil indicated Sand/Sandstone (2400-2460') = medium light gray; fine to coarse lower, especially fine upper to medium; subangular to some subrounded; moderate to high sphericity; moderately to poorly sorted and grain and matrix supported in light gray to white ashy clay matrix; 70% quartz, and 30% gray to black to green to rust to pink including mafics, chert and partially siliceous carbonaceous and clay to slightly chloritic clay lithics and trace micas; estimate poor to some fair mostly clay infill porosity; no oil indicated. g EPOCH 8 · · · (.M)Marathon Oil Company - Falls Creek #4 Sandstone/Sand (2460-2530') = medium light gray; fine to coarse, especially fine upper to coarse lower, and locally scattered coarse fragments to trace pebble; subangular to angular to occasionally subrounded; moderate to high sphericity; poor1y to moderately sorted and matrix and grain supported in white to light gray ashy clay; 65% quartz, and 35% gray to black to green to rust including mafics and other igneous, chert, siliceous to partially siliceous lithics and trace micas especially dark micas; estimate poor to occasional fair clay infill porosity; no oil indicators. Conglomeratic SandlSandstone (2530-2605') = medium light gray to some light gray; fine to coarse and scattered coarse fragments and locally pebbles; angular to subrounded; poorly to some moderately sorted and mostly matrix supported in ashy matrix; occasional streaks grading to tuffaceous claystone and ash fall tuff; 60% quartz, and 40% gray to black to green to rust to pink to white grains including igneous, chert and siliceous lithics; estimate mostly poor to occasional fair porosity; no oil indicators. Sandstone/Conglomeratic Sandstone (2605-2795') = light to mostly medium gray; very fine to occasionally coarse grain, dominantly medium grain; complete range of rounding from very angularto rounded; generally poorly sorted; poor to moderate sphericity with some unbroken pebbles being near1y spherical; appears in sample as mostly loose, disaggregated grains, but in some samples up to 30% is in weakly cemented, friable clusters with a very light gray to white clay/ash cement; occasional traces of very hard, well cemented thin laminar clusters with a calcareous cement giving an immediate strong acid reaction; sand is composed of 60-70% clear, milky, smoky and gray opaque quartz, 30-40% black to dark gray chert, conspicuous pink feldspar clasts some as inclusions in quartz, coal fines and other undifferentiated carbonaceous matter, trace tounnaline, rutile, mica moderate igneous rock fragments; up to 20% bit shattered conglomerate pebbles mostly of milky to clear quartz; common thin lamina of finn gray tuffaceous claystone; fair to moderate in situ porosity, no visible hydrocarbon indicators. Tuffaceous Claystone (2710-2815') = light to medium gray with rare medium brown; soft and mushy to fair1y finn; silty, gritty texture where glass shards are common, but very smooth and finn to pasty where shards are absent; occurs as rounded lumps and occasional semi blocky cuttings; the brown colored phase has abundant very finely disseminated carbonaceous specks; occurs as thin lamina and interbeds. Coal (2815-2840')=very dark brown to black; finn to very hard with some brittle; smooth to matte surface texture; mostly dull luster, rarely shiny; occurs as blocky, irregular cuttings, occasionally tabular; rare thin ashy silty laminations; rarely grades to dark brown carbonaceous shale ash content increases at base of coal; visible, vigorous outgassing bubbles. Tuffaceous Siltstone/Claystone (2845-3020') = light gray to very light gray some with faint grayish brown hue; soft and soluble to slightly finn; coarse silty to fine silty texture and often sandy with slight to moderate very fine to fine grains; some with slight carbonaceous fines; some interbedded light medium to medium gray tuffaceous claystone some with greenish hue and some with brownish hue; occasionally grading silty ash fall tuff to trace greasy smectite; some grading sandstone with mostly very fine to medium lower grains and locally conglomeratic with pebbles of chert and greenstone. SandstonelSand (2920-3100') = medium light gray to light gray; medium to very fine grains, especially fine to medium lower, and scattered coarse lower grains; subangular to angular; moderate overall sphericity; poor1y to moderately sorted and estimate grain and matrix supported in light gray slightly silty ashy matrix; slight calcareous yellowish gray to white "calcite" matrix assoc. well consolidated sandstone; locally planar coal and carbonaceous contact; 60% quartz, and 40% gray to black to green to rust and pink to rare tan mostly hard grains of chert and silicates and some partially siliceous lithics; estimate poor to some fair clay ¡nfill porosity; no oil indicators. Tuffaceous Claystone/Siltstone (3020-3180') = medium gray to medium light gray often with faint brownish to rare moderate brownish hue; soft and soluble to slightly finn; amorphous to irregular blocky to occasional slight incipient fissility; smooth to some silty texture; some slightly organic with traces carbonaceous fines and flakes; rare grading carbonaceous shale associated with coal; often silty and sandy grading tuffaceous siltstone and sandstone; occasionally calcareous especially slightly finn pieces grading shale. g EPOCH 9 (.M)Marathon Oil Company - Falls Creek #4 · Coal (3095-3210') = grayish black to some brownish black; finn and brittle to slightly finn and crumbly to slightly malleable; some visible lamina with platy to flaky fracture; some irregular hackly to rare conchoidal fracture; lignite to subbituminous locally grading carbonaceous shale with increase in organic clay content; interbedded to interlaminate with tuffaceous to carbonaceous claystone and sandstone. Sandstone/sand (3180-3340') = medium light gray; very fine upper to medium lower grains, and slightly scattered medium upper to coarse lower; angular to subangular; overall moderate sphericity; poorly sorted and mostly matrix supported in tuffaceous clay; grading to and interbedded with variably sandy and silty tuffaceous claystone and siltstone; 70% quartz, and 30% gray to gray to dark brown to black to minor green and rust to pink mostly hard grains including silicates and chert and partially siliceous carbonaceous fines and other lithics, and trace micas especially dark micas; estimate mostly poor to rare fair clay infill porosity; no oil indicators. Sand/Sandstone (3345-3430') = medium gray to medium light gray; very fine upper to coarse lower, especially fine to medium, and slightly scattered coarse upper grains; subangular to subrounded; moderate to high sphericity; moderately to poorly sorted and estimate mostly grain supported in ashy clay matrix; 60% quartz, and 40% mostly gray to black to minor rust, dark brown, and trace green mostly hard grains including silicates and mafics and chert and partially siliceous carbonaceous fines and other lithics; locally some thinly interbedded coal and occasionally grading tuffaceous claystone; estimate some fair to poor porosity; no oil indicators. · Tuffaceous Claystone (3400-3510') = medium light gray to medium gray often with faint bluish hue and occasionally with slight to moderate brownish hue; moderately soft to soft and soluble; slightly silty texture overall; often sandy grading grain supported sandstone; occasionally slightly organic with slight carbonaceous fines and flakes to occasionally grading organic claystone and shale associated with coal; locally grading pebble conglomerate; non calcareous. Coal (3430-3565') = grayish black to some brownish black; slightly finn and crumbly to finn and brittle; common visible lamina with platy to flaky fracture; occasionally hackly to rare conchoidal fracture; lignite to occasionally subbituminous; thinly bedded to thinly laminated in variably organic claystone, carbonaceous shale, and sandstone. SandstonelSand (3510-3620') = medium light gray; very fine to medium lower grains, and slightly scattered to locally common medium upper to coarse lower and trace coarse; angular to subangular; overall moderate sphericity; poorly to moderately sorted and matrix and grain supported; grading to and interbedded with variably sandy and silty tuffaceous claystone and minor siltstone; 70% quartz, and 30% dark brown to black to gray to rare rust to pink grains including variably siliceous carbonaceous fines and other lithics, silicates, mafics, and chert; estimate poor to some fair porosity; no oil indicators. Tuffaceous Claystone (3620-3100') = light to medium gray, occasionally bluish gray rarely light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes finn consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, otherwise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps and occasional finn blocky cuttings with very faint lamina; non to minor calcareous. · Sandstone (3100-3180') = light to medium gray; fine to medium grain with trace to lower coarse grain; angular to sub rounded with most grains sub angular; poor to fair sphericity; moderately to well sorted; very friable and poorly indurated; appears in sample as almost 100% disaggregated, loose grains with no trace of matrix or cement; individual quartz grains often have a frosted surface texture; few cemented clusters have a very light gray to white ashy, clayey matrix; most of this matrix washes out during sample preparation; sand is composed of 50% clear to milky quartz and 50% very fine grain, dark gray igneous rock fragments, gray feldspar and dark gray chert; very little to no conglomerate; estimate fair to good in situ porosity; no visible hydrocarbon indicators, no fluorescence. g EPOCH 10 · · · (.M)Marathon Oil Company - Falls Creek #4 Sandstone (3780-3990') = medium to dark gray; fine to medium grain dominantly lower medium grain; angular to sub rounded with most grains sub angular; poor to fair sphericity; moderately to well sorted; very friable and poor1y indurated; appears in sample as almost 100% disaggregated, loose grains with no trace of matrix or cement; individual quartz grains often have a frosted surface texture; few cemented clusters have a very light gray to white ashy, clay matrix; most of this matrix washes out during sample preparation; sand is composed of 50% clear to milky quartz and 50% very fine grain, dark gray igneous rock fragments, gray feldspar and dark gray to black chert; little to no conglomerate; as clay content increases, the sandstone grades to a sandy claystone; moderate in situ porosity; no visible hydrocarbon indicators, no fluorescence. Coal (3995-4100') = grayish black to brownish black to dusky brown; slightly firm and crumbly to firm and brittle; common visible lamina with flaky to platy fracture to some irregular hackly to rare conchoidal fracture; lignite to some subbituminous; mostly with slight to moderate organic clay content occasionally grading to carbonaceous shale; thinly interbedded to inter1aminated in various lithologies. Sand/conglomeratic Sand (3960-4080') = medium gray to medium light gray; very fine to coarse, especially fine upper to medium, and scattered to locally common very coarse, coarse fragments, and pebbles; subangular to angular, to some subrounded slightly more evident in coarser and non quartz lithics; poor1y to moderately sorted and grain and matrix supported in ashy clay; locally grading pebble conglomerate; 65% translucent to opaque quartz, and 35% mostly dark gray metalithics, silicates, and partially siliceous lithics and chert; estimate poor to fair porosity; no oil indicators. Tuffaceous Claystone (4100-4200') = medium light gray to light gray to occasionally with brownish hue to brownish gray; soft and soluble to slightly firm; amorphous to some with slight incipient fissility; smooth to some silty texture; often with slight to some moderate thin flakes and partings to laminations of carbonaceous matter and coal; possible thin beds coal. Coal = black to brownish black, flaky to splintery to occasionally hackly to conchoidal; moderately firm and brittle to slightly firm and crumbly. Conglomeratic Sand/Sand (4080-4260') = medium gray; very fine to coarse lower, especially fine to medium, and scattered to locally common coarse upper to pebble; subangular to some subrounded; moderate to high sphericity; moderately to poor1y sorted and grain and matrix supported in ashy clay; 50% quartz, and 50% mostly gray to black metalithics, chert, and variably siliceous lithics; probably grading to and with thin interbeds of tuffaceous claystone and coal; estimate fair to poor porosity and permeability; no oil indicators. Sand/Conglomeratic Sand (4260-4400') = medium gray to medium dark gray; very fine to very coarse, especially fine to coarse lower, and scattered fragments and minor pebbles; locally grading to conglomerate; angular to subrounded and some coarser fraction and pebbles rounded; includes some flat grains with rounded edges; moderate to some high sphericity; poor1y to moderately sorted and matrix and grain supported in ashy clay; 50-60% quartz, and 40-50% mostly gray to black metalithics, chert, and variably siliceous lithics; probably grading to and interbedded with tuffaceous claystone and locally interbedded coal; estimate poor to fair intergranular porosity and permeability; no oil indicators. Coal (4315-4410') = grayish black to brownish black; moderately firm and brittle to slightly firm and crumbly; flaky to platy fracture with common dark brown organic claystone on laminar partings; locally inter1aminated to thinly interbedded in sandy claystone and sand; lignite to minor subbituminous and occasionally grading carbonaceous shale or variably organic claystone with carbonaceous partings. [:I EPOCH 11 (.M)Marathon Oil Company - Falls Creek #4 . Sandstone (4410-4605') = dark to medium gray; fine to medium grain with trace of coarse grain; subangular to subrounded, with varying percentages of angular fragments; moderately well sorted; fair to some poor sphericity; appears in sample as nearly 100% loose disaggregated grains with no visible matrix or cement; very rare grain clusters preserved with very light gray ashy clay matrix or calcite cement; varies from grain supported to matrix supported as clay matrix increases; rare to moderate bit broken pebbles of mostly opaque to gray chert and very rare light tan quartzite; sand is composed of 30- 50% clear to gray opaque quartz; 50-70% dark gray to black very fine grain metamorphic rock fragments, mafic minerals, coal fines and mica; the high percentage of dark minerals imparts the dark color to the overall sample; grades to and interbeds with gray carbonaceous claystone containing thin lamina of black to very dark brown coaly carbonaceous material; no visible hydrocarbon indicators, no fluorescence. Tuffaceous Claystone (4605-4685') = light to medium gray, occasionally bluish gray rarely light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes finn consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, otherwise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps, mushy indistinct clots and occasionally finn blocky cuttings with very faint lamina; non to minor calcareous. . Sandstone (4685-4740') = medium to dark gray with dark gray predominating; fine to upper medium grain with trace of very fine; angular to sub rounded, dominantly sub angular; moderately well sorted; fair sphericity; variable percent of bit shattered conglomerate pebbles ranging from 0-30% of total sample, generally less than 20%; sample appears as nearly 100% loose grains with very few visible cemented clusters; rarely visible light gray clay matrix material washes out during sample cleaning; generally grain supported clast framework; sand is composed of 50% clear to cloudy opaque quartz, 50% very dark gray, fine grain metamorphic and igneous lithic fragments, coal fines, mafic minerals, chert and rare epidote; overall high proportion of dark clasts gives the bulk sample its dark gray color; occasional thin interbeds of black to dark gray woody to coaly carbonaceous matter with thin ash lamina on partings no visible hydrocarbon indicators. Sandstone (4740-4900') = dark to medium gray; fine to medium grain with trace of coarse grain; subangular to sub rounded, with varying percentages of angular fragments; moderately well sorted; fair to moderate sphericity; appears in sample as nearly 100% loose disaggregated grains with no visible matrix or cement; very rare grain clusters preserved with light gray ashy clay matrix or calcite cement; composed of 30-50% clear to gray opaque quartz; 50-70% dark gray to black very fine grain metamorphic rock fragments, mafic minerals, coal fines and mica; grades to and interbeds with gray carbonaceous claystone, occasional coal and carbonaceous shale interbeds; rarely grades to tuffaceous siltstone; estimate poor to some fair porosity and penneability; no oil indicators. Coal (4930-4980') = grayish black to black, some with faint brownish hue; very finn and brittle to some slightly finn and crumbly; irregular platy to conchoidal, to some flaky fracture with faint organic clay residue on planar surfaces; subbituminous to bituminous; massive to interbedded to flakes and laminations in gray to light gray tuffaceous claystone; trace amber. Poor sample quality 4900-5000' due to cement and bicarbonate contamination. Sand/Conglomeratic Sand (4980-5100')=medium dark gray; fine to coarse lower and slightly scattered to rare common very coarse grains and fragments; subangular to angular; moderate to moderately high sphericity; moderately to poorly sorted and estimate mostly grain supported in ashy clay matrix; locally grading to conglomerate; 30% quartz, and 70% variably gray to dark gray metalithics and partially siliceous lithics; massive to interbedded with tuffaceous claystone and siltstone, some platy and partially siliceous and occasionally calcareous especially siltstone, locally some ash fall tuff and carbonaceous shale and coal; estimate fair to some poor porosity and penneability; no oil indicators. . [:I EPOCH 12 · · · (.M)Marathon Oil Company - Falls Creek #4 Conglomeratic SandlSand (5100-5190') = medium dark gray; fine to coarse lower, especially fine upper to medium, and scattered coarse grains and rock fragments; subrounded to subangular; moderately high to moderately low sphericity; common sub planar grains with rounded edges; estimate mostly grain supported in ashy matrix with thinly interbedded tuffaceous claystone and siltstone and locally grading conglomerate; 20-30% quartz, and 70-80% medium to dark gray and trace green including metalithics and variably siliceous and minor calcareous lithics; estimate mostly fair porosity; no oil indicators. Tuffaceous Claystone (5190-5333') = medium gray to light gray to some brownish gray; soft and soluble to some finn and slightly to moderately calcareous; mostly smooth to some silty texture; often with slight to some moderate carbonaceous flakes and micro partings, including some slightly to moderately organic claystone; locally interlaminated to thinly bedded carbonaceous shale and coal; locally grading ash fall tuff. Coal (5295-5310') = grayish black some with brownish hue; slightly finn and flaky to crumbly, to finn and brittle with irregular to platy to conchoidal fracture; flaky pieces with organic clay residue on partings; lignite to subbituminous; traces of pyrite. Sand/Conglomeratic Sand (5215-5400') = medium dark gray to medium gray; fine upper to coarse lower and scattered very coarse and fragments; subangular to angular; moderately to poorly sorted and grain and matrix supported in ashy clay, locally matrix supported in calcite; 30-40% quartz, and 60-70% gray to dark gray metalithics and variably siliceous lithics including coal and carbonaceous debris; some interbedded tuffaceous claystone variably organic with partings of carbonaceous matter and coal; possible locally thin interbeds of coal; estimate mostly poor clay and calcite filled to some fair porosity; no oil indicated. Tuffaceous Claystone/Siltstone (5280-5460') = medium light gray to light gray some with faint brownish hue, to rare brownish gray; soft and soluble; smooth to some silty texture; some slightly sandy; often slight to occasional moderate carbonaceous matter and partings; locally streaks to interbeds of coal; mostly noncalcareous; occasionally calcareous associated with sandstone and coal debris. Tuffaceous Claystone/Siltstone (5460-5510') = medium light gray to light gray some with faint brownish hue, to brownish gray; soft and soluble; smooth to some silty texture; some slightly sandy; often slight to some moderate carbonaceous matter and partings; locally streaks to interbeds of coal; mostly non calcareous; occasionally calcareous including calcite. Tuffaceous Claystone/Siltstone (5510-5570') = medium light gray to light gray some with faint brownish hue, to some brownish gray; soft and soluble; smooth to some silty texture; some sandy; often slight to some moderate carbonaceous matter and partings; occasional streaks to interbeds of coal; mostly non calcareous; occasionally streaks hard calcareous claystone and streaks sandstone with calcite matrix; possible interbedded tuffaceous sand. Sand/Sandstone (5570-5710') = medium gray to medium dark gray; very fine to medium grains, and scattered very coarse and rock fragments; angular to subangular; poorly sorted and grain and matrix supported; common intergranular calcite; 40% quartz, and 60% mostly variably gray to black to minor white variably siliceous to calcareous to carbonaceous lithics and metalithics; probably grading to and interbedded with tuffaceous claystone and siltstone and coal; estimate mostly poor to locally fair porosity; no oil indicators. Tuffaceous Claystone/Siltstone (5580-5720') = medium light gray to light gray some with faint brownish hue, to some brownish gray; soft and soluble; smooth to some silty texture; some sandy; often slight to some moderate carbonaceous matter and partings; occasional streaks to interbeds of coal; mostly non calcareous; occasionally streaks hard calcareous claystone and streaks to interbedded with sandstone/sand. g EPOCH 13 · · · (.!!)Marathon Oil Company - Falls Creek #4 Coal (5700-5750') = grayish black to black to brownish black; slightly finn and flaky to crumbly, to finn and hackly to platy to rare conchoidal; some residue organic claystone on flaky partings; some clayey; lignite to occasionally subbituminous; massive to occurs as thin beds and laminations in tuffaceous claystone. Tuffaceous Claystone (5750-5820') = light to medium gray, occasionally bluish gray rarely light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes finn consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, otherwise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps, mushy indistinct clots and occasionally finn blocky cuttings with very faint lamina; non to minor calcareous. Sandstone (5820-5960') = dark to medium gray; fine to medium grain with trace of coarse grain; subangular to sub rounded, with varying percentages of angular fragments; fair1y well sorted; fair to moderate sphericity; appears in sample as near1y 100% loose disaggregated grains with no visible matrix or cement; very rare grain clusters preserved with light gray ashy clay matrix or calcite cement; composed of 40-50% clear to gray opaque quartz; 50-60% dark gray to black very fine grain metamorphic rock fragments, mafic minerals and common carbonaceous matter consisting of low grade coal, carbonaceous shale, undifferentiated humic matter, and carbonaceous siltstone grades to and interbeds with gray carbonaceous claystone, thin lignitic coals and brown, fissile carbonaceous shale; infer fair to good porosity; no hydrocarbon indicators, no fluorescence Tuffaceous Claystone (5960-6020') = light to medium gray, occasionally bluish gray rarely light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes finn consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, otherwise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps and mushy runny clots; slightly to moderately calcareous. Sandstone (6020-6130') = dark to medium gray; fine to medium grain with trace of coarse grain; subangular to sub rounded, with varying percentages of angular fragments; moderately well sorted; fair to moderate sphericity; appears in sample as nearly 100% loose disaggregated grains with no visible matrix or cement; very rare grain clusters preserved with light gray ashy clay matrix or calcite cement; very little to no conglomerate pebbles; composed of 30-50% clear to gray opaque quartz; 50-70% dark gray to black very fine grain metamorphic rock fragments, mafic minerals, coal fines and mica; grades to and interbeds with gray tuffaceous claystone; estimate poor to some fair porosity; no oil indicators. Tuffaceous Claystone (6120-6240') = light gray to medium light gray to some medium gray to brownish gray; mostly soft and soluble, to moderately soft to slightly finn with increasing organic content, to occasionally finn and slightly to moderately calcareous including calcite; smooth to some silty to minor sandy; mostly with slight to some moderate flakes and partings; flakes often stacked with variably organic clay residue to thin partings between flakes, and grading to carbonaceous shale, to coal streaks and lamina; some interbedded coal. Coal (6125-6190') = grayish black to black to dark grayish brown; mostly slightly finn and flaky to crumbly, to some finn and hackly to rare platy to conchoidal; low grade lignite with variable organic clay content occasionally grading to subbituminous in thicker coal beds; inter1aminated to interbedded in tuffaceous claystone and carbonaceous shale. Tuffaceous Claystone (6240-6400') = light gray to medium light gray to medium dark gray to brownish gray; mostly soft to moderately soft and soluble, to slightly finn with increasing organic content and moderately soluble, to occasionally finn to hard and variably calcareous including calcite; mostly smooth to slightly silty, to often variably sandy; mostly with slight to some moderate flakes and partings; flakes often stacked with organic clay varying from residue to thin partings between flakes, and to grading to carbonaceous shale to coal streaks and lamina; some interbedded coal. U EPOCH 14 (.M)Marathon Oil Company - Falls Creek #4 · Tuffaceous Claystone/Siltstone (6400'-6530') = light gray to medium light gray to medium dark gray to brownish gray; mostly soft to moderately soft and non to some slightly calcareous and soluble, to moderately soft to slightly finn with increasing organic content, to rare finn to hard when calcareous including calcite; smooth to some silty to fine sandy texture; possible interbedded very fine to coarse grain sand; mostly with slight to some moderate flakes and partings; some grading to organic claystone and carbonaceous shale; some thin beds and laminations of coal. Sand/Sandstone (6315-6530') = medium dark gray to medium gray; very fine to coarse especially fine to medium, sub-angular to subrounded and some angular; overall moderate to high sphericity; some grains lightly frosted clay; estimate matrix and grain supported in ashy clay grading to and interbedded with tuffaceous claystone and siltstone; 40% quartz, and 60% gray to black metalithics, mafics, and partially siliceous lithics including carbonaceous matter and coal; estimate poor to some fair porosity; no visible oil indicators. Tuffaceous Claystone (6530-6660') = medium gray to medium light gray to medium dark gray to brownish gray; moderately soft and moderately soluble, to soft and soluble; smooth earthy to some silty to fine sandy texture; mostly non calcareous to occasionally slightly calcareous; mostly slightly organic to some grading carbonaceous shale; mostly slight to some moderate carbonaceous matter and flakes; some interlaminated to interbedded coal. · Sandstone (6660-6770') = dark to medium gray; fine to medium grain with very rare coarse grain; subangularto sub rounded, with small percentage of angular fragments; moderately well sorted; fair to moderate sphericity; appears in sample as around 90% loose disaggregated grains with no visible matrix or cement; uncommon grain clusters preserved with light gray ashy clay matrix or calcite cement; composed of 30% clear to gray opaque quartz; 70% dark gray to black very fine grain metamorphic rock fragments, mafic minerals and common carbonaceous matter consisting of low grade coal, carbonaceous shale, undifferentiated humic matter, and carbonaceous siltstone grades to and interbeds with gray carbonaceous claystone, thin lignitic coals and brown, fissile carbonaceous shale; infer fair to good porosity; the overall dark color of this sand is due to the very high percentage of dark gray metamorphic rock fragments and undifferentiated carbonaceous matter, no hydrocarbon indicators, no fluorescence Carbonaceous Material (6710-6820') = black to very dark brown; various fonns of carbonaceous matter including lignitic to sub bituminous coal, dark brown, woody, fibrous, fissile carbonaceous shale; finely disseminated brown to black specks and amorphous clots and lumps of soft humic matter; and black, micro thin to laminar and platy, papery flexible sheets and films of undifferentiated carbonaceous residue. Tuffaceous Claystone (6770-6950') = light to medium gray, occasionally bluish gray rarely light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes finn consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, otherwise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps and mushy runny clots; slightly to moderately calcareous; common dark brown micro laminations and specks of carbonaceous material in the brown phase of this claystone. Coal (6950-7005') = very dark brown to black; finn to hard with some brittle; smooth to matte surface texture; shiny vitreous luster; splintery to occasional planar fracture, very rarely conchoidal; occurs as mostly tabular, blocky and irregular cuttings; rare micro thin laminations of ashy siltstone; moderate outgassing bubbles visible when cuttings are fresh; interbedded with dark brown, fissile, woody carbonaceous shale. · [j EPOCH 15 · · · (.M)Marathon Oil Company - Falls Creek #4 Sandstone (7010-7100') = light to medium gray; fine to medium grain with trace of lower coarse; subangular to sub rounded, with some well rounded grains; moderately to very well sorted; moderate to good. sphericity; appears in sample as nearly 100% loose disaggregated grains with no visible matrix or cement; very rare grain clusters preserved with light gray ashy clay matrix or calcite cement; composed of 60-70% clear to gray opaque quartz; 30-40% dark gray to black very fine grain metamorphic rock fragments, mafic minerals, coal fines and mica; grades to and interbeds with gray carbonaceous claystone; trace to no bit broken conglomerate pebbles; this sandstone is characterized by its unifonnity in grain size, rounding and sphericity; estimate good in situ porosity; no visible hydrocarbon indicators; no fluorescence. Tuffaceous Claystone (7090-7190') = medium gray to light brownish gray to very light gray to grayish brown; mostly soft to moderately soft and soluble; occasionally slightly finn to finn grad-medium dark gray calcareous shale; smooth to silty to fine sandy texture; locally grading fine to medium grain sandstone; locally grading to ash fall tuff; mostly slight to some moderate disseminated carbonaceous matter and flakes; variably sprinkled organic brown clay, especially lighter gray ashy clays; some grading to carbonaceous shale with increasing carbonaceous matter and partings; locally interbedded with coal; non to some slightly calcareous. Coal (7135-7222') = grayish black to brownish black; moderately finn to finn with irregular to hackly to platy fracture, to slightly finn with flaky fracture, to finn with conchoidal fracture; often with visible lamina commonly parting easily with clay residue on partings; lignite to sub bituminous; massive to some thinly bedded. Sandstone (7220-7380') = light gray to medium light gray to light brownish gray, very fine to coarse lower, especially medium to fine, and locally slight very coarse to pebble; subangular to subrounded to angular especially assoc. calcite; moderately to poorly sorted and some graded bedding; matrix supported in ashy clay and calcite to grain supported in clay and variable calcite; mostly grain supported with coarser fraction; interbedded and grading to tuffaceous siltstone and tuffaceous claystone; 70% quartz, and 30% gray to black to minor green to tan including coal and carbonaceous fines and other lithics and metalithics; some fair intergranular porosity with decreasing clay and calcite fill in grain supported sandstone; no oil indicators. Tuffaceous Siltstone/Claystone (7315-7485') = medium gray to medium light gray to light brownish gray to rare grayish brown; soft to moderately soft and soluble; slight silty to silty to very fine sandy texture; mostly with very slight to slight very finely disseminated carbonaceous matter and flakes and occasional partings; some slightly to moderately organic clay content; rare grading to carbonaceous shale; grading to and interbedded with fine and some coarser sandstone; mostly non to occasionally slightly calcareous. Sandstone (7380-7610') = medium light gray to light gray to light brownish gray; mostly very fine to fine, to locally fine to medium with scattered coarse; angularto subrounded; low to moderately high sphericity; mostly moderately sorted and grain and matrix supported in ashy sometimes variably organic clay, with some calcite fill especially coarser sandstone; 70% quartz and 30% mostly coal and carbonaceous fines and some partially siliceous lithics and minor metalithics; estimate some fair porosity and penneability; no oil indicators. Coal (7485-7600') = grayish black to brownish black; moderately finn to finn with irregular to hackfy to platy fracture, to slightly finn with flaky fracture, to finn with conchoidal fracture; often with visible lamina commonly parting easily with some clay residue on partings; lignite to subbituminous; massive to some thin zones and laminations in tuffaceous siltstone and carbonaceous shale. [:I EPOCH 16 · · · (.M)Marathon Oil Company - Falls Creek #4 Sandstone (7615-7665') = medium light gray; very fine to coarse lower, especially medium to fine, and locally scattered very coarse and pebble fragments; subangular; moderate to high sphericity; moderately sorted and probably mostly grain supported in ashy clay matrix; some calcite cement and in matrix; 80% quartz, and 20% gray to black to minor green, pink, and tan, including metalithics or mafics, partially siliceous lithics, and minor feldspar; massive with probable streaks grading tuffaceous and variably organic siltstone and claystone; estimate poor to fair porosity and permeability; no fluorescence or other oil indicators. Tuffaceous Siltstone/Claystone (7600-7760') = medium gray to light brownish gray to medium light gray; soft to moderately soft and soluble; silty to slightly silty to very fine sandy texture; often variably organic including organic clay and carbonaceous fines; some siltstone slightly to moderately calcareous and traces hard calcite streaks; overall mostly non calcareous; some grading tuffaceous and variably organic very fine grain sandstone; interbedded with coarser sands and minor coal. Tuffaceous Claystone (7760-7835') = light to medium gray, occasionally bluish gray and light brownish gray; poor to moderately cohesive; mushy to gummy to sometimes firm consistency; soluble in water and part washes out during sample preparation; silty, gritty texture where shard concentration is high, othelWise smooth; moderate to high percentage of shards and silt embedded in matrix; occurs in sample as soft, flow rounded lumps and mushy runny clots; slightly to moderately calcareous; common dark brown micro laminations and specks of carbonaceous material in the brown phase of this claystone. Coal (7835-7910') = very dark brown to black; firm to hard with some brittle; smooth to matte surface texture; shiny vitreous luster; splintery to occasional planar fracture, very rarely conchoidal; occurs as mostly tabular, blocky and irregular cuttings; rare micro thin laminations of ashy siltstone; moderate outgassing bubbles visible when cuttings are fresh; interbedded with dark brown, firm, fissile, carbonaceous shale. U EPOCH 17 (.M)Marathon Oil Company - Falls Creek #4 . SURVEY INFORMATION Measured Depth Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Feet N(+) S(-) E(+) W(-) Degrees/100' 0 0 0 0 0 0 0 145.00 0.80 42.80 42.80 0.74N 0.69E 0.55 207.00 0.60 343.40 206.99 1.37N 0.89E 1.15 292.00 2.50 265.50 291.96 1.65N 1.09W 2.88 388.00 6.60 254.20 387.64 0.015 8.49W 4.35 484.00 10.60 249.10 482.54 4.675 22.05W 4.24 578.00 14.50 254.70 574.28 10.865 41.48W 4.34 675.00 17.90 257.10 667.42 17 .405 67.74W 3.57 771.00 22.10 256.60 757.61 24.885 99.70W 4.38 867.00 26.80 258.80 844.98 33.275 138.52W 4.99 961.00 30.70 257.50 927.37 42.585 182.75W 4.20 1022.00 31.30 257.50 927.37 42.585 182.75W 4.20 1118.00 34.80 257.30 1060.12 60.395 264.60W 3.67 1212.00 37.30 258.00 1136.11 72.215 318.63W 2.70 1308.00 40.20 257.10 1210.97 85.185 377.30W 3.08 1404.00 43.60 258.30 1282.42 98.815 439.93W 3.64 1500.00 46.40 258.40 1350.29 112.525 506.41W 2.92 1595.00 49.70 258.70 1413.79 126.545 575.65W 3.48 1690.00 55.00 256.00 1471.80 143.065 648.99W 6.01 1787.00 60.40 255.70 1523.62 163.105 728.46W 5.57 . 1883.00 60.10 257.50 1571.26 182.425 809.53W 1.66 1979.00 61.00 257.70 1618.46 200.375 891.18W 0.95 2074.00 63.10 258.00 1662.98 218.035 973.21W 2.23 2170.00 64.20 256.20 1705.59 237.025 1057.11W 1.81 2267.00 64.10 256.20 1747.88 257.625 1141.94W 0.30 2361.00 63.70 256.90 1789.24 277.255 1224.04W 0.79 2458.00 62.40 256.70 1833.20 297.005 1308.22W 1.35 2552.00 64.00 257.20 1875.58 315.945 1389.95W 1.77 2649.00 65.50 257.80 1916.96 334.925 1475.60W 1.64 2745.00 64.90 257.60 1957.23 353.495 1560.75W 0.65 2839.00 64.50 257.20 1997.40 372.035 1643.68W 0.57 2935.00 64.30 256.80 2038.88 391.505 1728.04W 0.43 3031.00 64.30 257.60 2080.51 410.675 1812.39W 0.75 3127.00 63.80 258.30 2122.52 428.695 1896.81W 0.84 3223.00 63.40 257.50 2165.20 446.715 1980.89W 0.85 3318.00 . 62.70 257.70 2208.26 464.905 2063.59W 0.76 3414.00 61.90 257.80 2252.88 482.935 2146.66W 0.84 3510.00 59.60 257.10 2299.79 501.125 2228.41W 2.48 3606.00 56.50 256.10 2350.58 519.995 2307.64W 3.35 3700.00 54.00 255.60 2404.16 538.865 2382.53W 2.70 3796.00 52.40 255.00 2461.66 558.365 2456.88W 1.74 3892.00 50.80 255.10 2521.29 577.775 2529.56W 1.67 3987.00 49.00 255.40 2582.48 596.285 2599.83W 1.91 4083.00 46.30 254.90 2647.15 614.455 2668.41W 2.84 4178.00 43.20 252.10 2714.61 633.405 2732.53W 3.87 4274.00 40.80 252.50 2785.95 652.935 2793.72W 2.52 ~ 4369.00 38.60 252.50 2859.04 671.185 2851.59W 2.32 4465.00 35.80 253.80 2935.50 688.025 2907.12w 3.03 4560.00 32.80 253.90 3013.97 702.915 2958.54w 3.16 g EPOCH 18 (.M)Marathon Oil Company - Falls Creek #4 .easured Depth Inclination Azimuth TV» Coordinates Dog Leg Feet Degrees Degrees Feet N(+) S(-) E(+) W(-) Degrees/100' 4655.00 30.20 253.80 3094.96 716.718 3006.21W 2.74 4751.00 27.70 253.80 3178.96 729.688 3050.83W 2.60 4845.00 24.90 256.20 3263.22 740.508 3091.04W 3.19 4941.00 24.20 256.80 3350.54 749.818 3129.82W 0.77 5037.00 24.10 256.00 3438.14 759.048 3168.00W 0.36 5132.00 24.80 257.60 3524.62 768.018 3206.28W 1.01 5228.00 24.50 255.70 3611.88 777.268 3245.23W 0.88 5323.00 24.40 254.30 3698.36 787.438 3283.21W 0.62 5419.00 25.50 256.60 3785.40 797.598 3322.40W 1.53 5514.00 25.30 255.40 3871.22 807.448 3361.94W 0.58 5609.00 25.10 255.70 3957.18 817.548 3401.11W 0.25 5705.00 24.60 255.40 4044.29 827.608 3440.17W 0.54 5801.00 24.90 254.40 4131.47 838.078 3478.98W 0.54 5897.00 24.60 253.00 4218.65 849.358 3517.55W 0.69 5992.00 24.10 253.10 4305.20 860.778 3555.02W 0.53 6088.00 24.90 252.80 4392.56 872.448 3593.08W 0.84 6184.00 25.00 253.40 4479.60 884.228 3631.82W 0.28 6280.00 24.70 254.20 4566.71 895.478 3670.56W 0.47 6376.00 24.20 255.50 4654.10 905.868 3708.91W 0.77 6470.00 24.40 256.90 4739.77 915.088 3746.48W 0.65 6566.00 24.70 255.40 4827.10 924.648 3785.20W 0.72 6661.00 25.00 255.70 4913.30 934.608 3823.86W 0.34 6757.00 24.50 255.30 5000.48 944.668 3862.77W 0.55 6853.00 23.90 255.00 5088.04 954.748 3900.81W 0.64 6947.00 23.70 256.80 5174.05 963.998 3937.60W 0.80 7044.00 24.80 256.70 5262.49 973.128 3976.37W 1.13 7139.00 25.20 256.10 5348.59 982.568 4015.40W 0.50 7235.00 24.40 254.70 5435.74 992.708 4054.36W 1.03 7331.00 25.50 255.20 5522.78 1003.218 4093.47W 1.17 7427.00 24.90 255.80 5609.64 1013.458 4133.04W 0.68 7523.00 24.00 255.50 5697.03 1023.308 4171.54W 0.95 7619.00 24.60 253.90 5784.52 1033.728 4209.64W 0.93 7715.00 26.10 255.30 5871.28 1044.638 4249.26W 1.68 7809.00 25.30 254.20 5955.98 1055.348 4288.59W 0.99 7850.00 25.10 254.70 5993.08 1060.028 4305.41W 0.71 7910.00 25.10 254.70 6047.41 1066.748 4329.96W 0.00 . g EPOCH 19 (M)Marathon Oil Company - Falls Creek #4 DAILY MUD PROPERTIES Date Depth MW Vis PV YP Gels Fluid Cake Solids OillWater Sand pH CI Ca Loss 1/19/04 121 8.8 215 10 58 30/35/36 12.2 2 3.5 0/96.5 TR 9.0 800 40 1/20/04 550 9.05 82 16 37 17/36/42 12.9 3 5 0/95 0.5 9.2 600 40 1/21/04 1268 9.25 135 20 34 24/52/54 9.6 2 5 0/95 0.5 8.9 350 32 1/22/04 1860 9.2 110 18 30 13/35/43 7 2 4 0/96 1 9.3 250 48 1/23/04 1860 9.3 110 22 26 13/32/35 7.8 2 5 0/95 1 9.1 200 40 1/24/04 1860 9.1 75 16 16 6/24/26 7.4 2 4.5 0/95.5 1 8.6 250 40 1/25/04 1860 9.1 50 16 16 5/8/9 8 2 4 0/96 1 8.5 200 60 1/26/04 1900 9.0 56 9 30 15/22/23 7.4 1 4.5 0/95.5 0.25 9.3 28000 40 1/27/04 2605 9.1 54 11 26 15/19/21 7.0 1 5.5 0/94.5 0.33 9.5 31000 60 1/28/04 3947 9.5 73 14 35 15/30/31 7.0 1 8 0/92 0.33 9.4 31000 100 1/29/04 4905 9.6 58 13 33 14/27/29 7.2 1 8.5 0/91. 5 0.33 9.5 31000 100 1/30/04 4900 9.6 65 13 31 12/22/23 6.6 1 9 0/91 0.33 9.3 30000 80 1/31/04 4900 9.5 57 12 26 8/16/19 6.1 1 7.5 0/92.5 0.25 9.2 29000 100 2/1/04 4920 9.0 55 11 23 9/17/18 5.8 1 4 0/96 TR 9.1 31000 60 2/2/04 6407 9.5 61 12 29 10/17/19 6.6 1 7.5 0/92.5 0.33 10.2 33000 40 2/3/04 7500 9.5 70 17 35 12/18/19 4.8 1 7.5 3/89.5 0.33 10.0 32000 60 2/4/04 7910 9.5 68 16 27 10/17/19 5.0 1 7.5 3/89.5 0.25 9.2 29500 60 2/5/04 7910 9.65 74 17 27 9/17/19 5.2 1 8 2.5/89.5 0.25 9.4 28500 40 2/6/04 7910 9.55 70 15 25 10/16/18 4.8 1 7.5 2.5/90 0.35 9.3 29000 40 2/7/04 7910 9.55 72 15 26 10/16/18 5.0 1 8 2.5/89.5 0.5 9.1 29000 40 . U EP~CH 20 . ~ . ~Marathon Oil Company - Falls Creek #4 BIT RECORD MARATHON OIL COMPANY FALLS CR. FALLS CREEK FIELD #4 KENAI PENNINSULA, AK From 101' to 7910' NABORS ALASKA API Number : 50-133-205-3300 DRILLING, RIG #129 JANUARY 20,2004 TO FEBRUARY 04.2004 BIT SIZE MAKE! TYPE SER NO. JETS DEPTH DEPTH FTG HRS ROP WOB RPM PP GRADE " I OUT I Avg Hi-Lo-Avg lfi-Lo-A vg Avg l- O-D-L-B- G- # IN OT-R --""-----------~ 1860 HC 710401 ' I' H-CT-G-D-I n~_3 .._ t8~Lª-C~~ .t="==-í4=i 791~3010 29~t·5f~·1~6f~t2930 ~~T-:= . ~ EP~(=H 21 . '@)Marathon Oil Company - Falls Creek #4 MORNING REPORTS . fI EP~CH 22 . . . . Marathon 011 Company DAIL Y WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 20, 2004 DEPTH 550.00 PRESENT OPERATION.. Drilling TIME 24:00:00 YESTERDAY 101.00 24 Hour Footage 449 CASING INFORMATION 20" @ 101' DEPTH INCLINATION AZIMUTH VERTICAl DEPTH SURVEY DATA 484.00' 10.60 249.1 482.54' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PUllED 1 16" He MX1 6013111 15c,3X18 101' 449' 8.12 DRilLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION 156.0 @ 137.00 12.3 @ 257.00 55.3 37.55512 ftIhr SURFACE TORQUE 2656 @ 530.00 0 @ 545.00 587.4 0 amps WEIGHT ON BIT 9 @ 505.00 0 @ 440.00 3.4 3.59483 Klbs ROTARYRPM 82 @ 256.00 0 @ 395.00 23.5 0 RPM PUMP PRESSURE 1016 @ 544.00 505 @ 129.00 732.4 965.04797 psi DRilliNG MUD REPORT DEPTH: 550' MW 9.05 VIS 82 PI! 16 yp 37 Fl 12.9 Gels 17/36142 Cl- 600 FC 31 SOL 5 SD 0.5 OIL 0 MBl 17.5 pH 9.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH lOW AVERAGE DITCH GAS 4 @ 543.00 0.3 @ 524.00 0.8 TRIP GAS.. NA CUTTING GAS 0 @ 550.00 0 @ 550.00 0.0 WIPER GAS.. NA CHROMATOGRAPHY(ppm) SURVEY.. METHANE(C-1) 651 @ 543.00 21 @ 524.00 84.4 CONNECTION GAS HIGH.. 0 ETHANE(C-2) 0 @ 550.00 0 @ 550.00 0.0 AVG.. 0 PROPANE(C-3) 0 @ 550.00 0 @ 550.00 0.0 CURRENT 0 BUTANE(C-4) 0 @ 550.00 0 @ 550.00 0.0 CURRENT BACKGROUND/AVG 4/1 PENTANE(c-5) 0 @ 550.00 0 @ 550.00 0.0 HYDROCARBONSHO~ NONE INTERVAL LlTHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO DATA PRESENT LITHOLOGY NO DATA DAilY ACTIVITY Epoch logged on 4:07 hrs at 101', base of conductor pipe, after spud well (tagged at 26' and began drilling 2:30 am). Drilled to SUMMARY 128' with bit and mud motor and 4' drill pipe. Changed BHA to include MWD tool and drilled to 200', kick off point. Worked on top drive, then drilled, mostly sliding, from 200' to 550'. Epoch PersonelOn Board" 2 Dally Cost $1954 Report by: Brian O'Fallon . . . Marathon Oil Company DAILY WELLSITE REPORT [j EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 21, 2004 DEPTH 12$7.00 PRESENT OPERATION.. Drilling TIME 24:00:00 YESTERDAY 55Q.00 24 Hour Footage 717 CASING INFORMATION 20" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1022' 31.30 258.10 979.66' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 1 16" HC MX1 6013111 15c,3X18 101' 1166' 21.68 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 147.6 @ 634.00 8.2 @ 990.00 65.5 98.38867 ftIhr SURFACE TORQUE 4008 @ 1171.00 0 @ 980.00 919.9 3309.86743 amps WEIGHT ON BIT 12 @ 1018.00 0 @ 634.00 7.1 5.62440 Klbs ROTARYRPM 84 @ 1248.00 0 @ 1237.00 23.1 84.04708 RPM PUMP PRESSURE 1503 @ 1151.00 824 @ 675.00 1120.4 1404.43994 psi DRILLING MUD REPORT DEPTH: 1268 MW 9.25 VIS 135 PV 20 yp 34 FL 9.6 Gels 24/52/54 CL- 350 FC 2/ SOL 5.0 SD 0.5 OIL 0 MBL 13.8 pH 8.9 Ca+ 32 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 62 @ 1158.00 1 @ 578.00 17.9 TRIP GAS" 9u CUTTING GAS 0 @ 1267.00 0 @ 1267.00 0.0 WIPER GAS: CHROMATOGRAPHY~pm) SURVEY" METHANE(C-1) 14028 @ 1158.00 169 @ 578.00 3722.9 CONNECTION GAS HIGH: 0 ETHANE(C-2) 0 @ 1267.00 0 @ 1267.00 0.0 AVG: 0 PROPANE(C-3) 0 @ 1267.00 0 @ 1267.00 0.0 CURRENT 0 BUTANE(C-4) 0 @ 1267.00 0 @ 1267.00 0.0 CURRENT BACKGROUND/AVG 19/18 PENTANE(C-5) 0 @ 1267.00 0 @ 1267.00 0.0 HYDROCARBONSHO~ NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO DATA PRESENT LITHOLOGY NO DATA DAILY ACTIVITY Drill from 550' to 1016', circulate hole clean and backream out of hole. Change BHA to Inciude 5" HWDP on trip in, and finish SUMMARY trip in with 4" DP. Wash to bottom on last stand, trip;gas 9 units, and drill ahead, mostly sliding from 550' to 1267'. Epoch Personel On Board: 2 Daily Cost ML: $1694 RW $260 Report by: Brian O'Fallon . . . Marathon Oil Company DAILY WELLSltE REPORT U EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 22, 2004 DEPTH 1860.00 PRESENT OPERATION= circulating to clean hole TIME 24:00:00 YESTERDAY 1267.00 24 Hour Footage 593 CASING INFORMATION 20"@101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1805' 61.60 257.2 1532.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TI8IC PULLED 1 16" HC MX1 6013111 15c,3X18 101' 1860' 1759' 37.46 casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134.9 @ 1577.00 5;5 @ 1759.00 55.8 60 ftIhr SURFACE TORQUE 4831 @ 1547.00 0 @ 1682.00 556.4 0 amps WEIGHT ON BIT 22 @ 1649.00 0 @ 1268.00 12.1 14.31648 Klbs ROTARY RPM 103 @ 1541.00 Ó @ 1617.00 12.3 0 RPM PUMP PRESSURE 1782 @ 1613.00 800 @ 1469.00 1593.9 1747 psi DRILLING MUD REPORT DEPTH: 1860' MW 9.2 VIS 110 PV 18 YP 30 FL 7.0 Gels 13/35/43 CL- 250 FC 21 SOL 4.0 SD 1.0 OIL 0 MBL 20 pH 9.3 Ca+ 48 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 63 @ 1800.00 7 @ 1462.00 22.2 TRIP GAS= NA CUTTING GAS 0 @ 1860.00 0 @ 1860.00 0.0 WIPER GAS= CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) 14640 @ 1800.00 1462 @ 1462.00 4550.1 CONNECTION GAS HIGH= 3 ETHANE(C-2) 0 @ 1860.00 0 @ 1860.00 0.0 AVG= 1 PROPANE(C-3) 0 @ 1860.00 0 @ 1860.00 0.0 CURRENT 0 BUTANE(c-4) 0 @ 1860.00 0 @ 1860.00 0.0 CURRENT BACKGROUND/AVG 15/22 PENT AN E(c-5) 0 @ 1860.00 0 @ 1860.00 0.0 HYDROCARBONSHO~ NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO DATA PRESENT LITHOLOGY NO DATA DAILY ACTIVITY SUMMARY Drill ahead, mostly sliding, from 1267' to 1$60', casing depth, and circulating to clean hole. Epoch Personel On Board= 2 Daily Cost ML: $1694 RW: $260 Report by: Brian O'Fallon · · · Marathon Oil Company DAILY WELLSITE REPORT ~ EPOCH Falls Creek #4 REPORT FOR Rowtand Lawson DATE Jan 23, 2004 DEPTH 1860.00 PRESENT OPERATION= Rig up to run 4" DP inside casing. TIME 24:00:00 YESTERDAY 1860.00 24 Hour Footage 0 CASING INFORMATION 20"@101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1805' 61.60 257.2 1532.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TlBlC PUllED 1 16" HC MX1 6013111 15c,3X18 101' 1860' 1759' 37.46 casing point DRilLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 1860 NA @ 1860 NA NA ftIhr SURFACE TORQUE NA @ 1860 NA @ 1860 NA NA amps WEIGHT ON BIT NA @ 1860 NA @ 1860 NA NA Klbs ROTARY RPM NA @ 1860 NA @ 1860 NA NA RPM PUMP PRESSURE NA @ 1860 NA @ 1860 NA NA psi DRilLING MUD REPORT DEPTH: 1860' MW 9.3 VIS 110 p.¡ 22 yp 26 Fl 7.8 Gels 13/32135 Cl- 200 FC 21 SOL 5.0 SD 1.0 Oil 0 MBl 20 pH 9.1 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH lOW AVERAGE DITCH GAS 46 @ 1860 6 @ 1860 15 TRIP GAS= 20u(1860) CUTTING GAS NA @ 1860 NA @ 1860 NA WIPER GAS.. CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) NA @ 1860 NA @ 1860 NA CONNECTION GAS HIGH= NA ETHANE(C-2) NA @ 1860 NA @ 1860 NA AVG= NA PROPANE(C-3) NA @ 1860 NA @ 1860 NA CURRENT NA BUTANE(C-4) NA @ 1860 NA @ 1860 NA CURRENT BACKGROUND/AVG 7/15 PENT AN E(C-5) NA @ 1860 NA @ 1860 NA HYDROCARBONSHO~ NA INTERVAL llTHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAilY ACTIVITY Continue circulating until hole clean, gas to 14 units, and trip out of hole without problems. Check bit, and trip to bottom, working SUMMARY through bridge or ledge at 1550'. Circulate hole clean, gas to 7 units with maximum 20 units of trip gas. Trip out of hole, lay down BHA, and rig up and run 13316" casing to bottom. Rig down after casing run and rig up to run Inner string, 4" DP, for cement. Epoch Personel On Board" 2 Daily Cost Ml: $1694 RW: $260 Report by: Brian O'Fallon . . . Marathon Oil Company DAIL Y WELLSITE REPORT ~ EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 24, 2004 DEPTH 1860.00 PRESENT OPERATION.. Nipple UP BOPs. TIME 24:00:00 YESTERDAY 1860.00 24 Hour Footage 0 CASING INFORMATION 20"@101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1805' 61.60 257.2 1532.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBfC PULLED 1 16" HC MX1 8013111 15c,3X18 101' 1860' 1759' 37.46 casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 1860 NA @ 1860 NA NA ftIhr SURFACE TORQUE NA @ 1860 NA @ 1860 NA NA amps WEIGHT ON BIT NA @ 1860 NA @ 1860 NA NA Klbs ROTARY RPM NA @ 1860 NA @ 1860 NA NA RPM PUMP PRESSURE NA @ 1860 NA @ 1860 NA NA psi DRILLING MUD REPORT DEPTH: 1860' MW 9.1 VIS 75 PV 16 yp 16 FL 7.4 Gels 6124/26 CL- 250 FC 21 SOL 4.5 SD 1.0 OIL 0 MBL 22.5 pH 8.6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 12 @ 1860 1 @ 1860 5 TRIP GAS.. 12u(1860) CUTTING GAS NA @ 1860 NA @ 1860 NA WIPER GAS.. CHROMATOGRAPHYwpm) SURVEY" METHANE(C-1) NA @ 1860 NA @ 1860 NA CONNECTION GAS HIGH.. NA ETHANE(c-2) NA @ 1860 NA @ 1860 NA AVG.. NA PRO PAN E(C-3) NA @ 1860 NA @ 1860 NA CURRENT NA BUTANE(C-4) NA @ 1860 NA @ 1860 NA CURRENT BACKGROUND/AVG 1/5 PENT AN E(c-5) NA @ 1860 NA @ 1860 NA HYDROCARBONSHO~ NA INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Finish running Inner string of 4" DP inside 133/8" casing, circulate and clean hole and treat mud prior to cement casing, SUMMARY maximum 12 units of gas down to 3 units before cement. Cement casing, 1 unit of gas before cament retums at surface. Wait on cement 8 hours and nipple down hydril and diverter system and begin nipple up BOPs. Epoch Personel On Board" 2 Dally Cost ML: $1694 RW: $260 Report by: Brian O'Fallon · Marathon 011 Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 25, 2004 DEPTH 1860.00 PRESENT OPERATION= Testing BOPs. TIM E 24:00:00 YESTERDAY 1860.00 24 Hour Footage 0 CASING INFORMATION 13318"@1840' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1805' 61.60 257.2 1532.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/BIC PULLED 1 16" HC MX1 6013111 15c,3X18 101' 1860' 1759' 37.46 casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 1860 NA @ 1860 NA NA ftIhr SURFACE TORQUE NA @ 1860 NA @ 1860 NA NA amps VVEIGHT ON BIT NA @ 1860 NA @ 1860 NA NA KIbs ROTARYRPM NA @ 1860 NA @ 1860 NA NA RPM PUMP PRESSURE NA @ 1860 NA @ 1860 NA NA psi DRILLING MUD REPORT DEPTH: 1860' MW 9.1 VIS 50 PV 16 YP 16 FL 8.0 Gels 51819 CL- 200 FC 21 SOL 4.0 SD 1.0 OIL 0 MBL 17.5 pH 8.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ 1860 NA @ 1860 NA TRIP GAS= NA CUTTING GAS NA @ 1860 NA @ 1860 NA WIPER GAS= CHROMATOGRAPHY~pm) SURVEY- METHANE(C-1) NA @ 1860 NA @ 1860 NA CONNECTION GAS HIGH- NA ETHANE(C-2) NA @ 1860 NA @ 1860 NA AVG.. NA PROPANE(C-3) NA @ 1860 NA @ 1860 NA CURRENT NA BUTANE(C-4) NA @ 1860 NA @ 1860 NA CURRENT BACKGROUND/AVG NA PENTANE(C-5) NA @ 1860 NA @ 1860 NA HYDROCARBONSHO~ NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Finish nipple up BOPs while building 700 barrels mud volume (FloPro) in pits, and testing BOPs. No circulating past 24 SUMMARY hours. · Epoch Personel On Board" 2 Dally Cost ML: $1694 RW: $260 Report by: Brian O'Fallon · . . . Marathon Oil Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 26, 2004 DEPTH 1939.00 PRESENT OPERATION= Drilling TIME 24:00:00 YESTERDAY 1860.00 24 Hour Footage 79 CASING INFORMATION 13318" @ 1640' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2170.00' 64.2 256.5 1705.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 2 12 114" HC MXC1 5044158 16c,3X18 1860 79 0.81 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 173.5 @ 1873.00 28.0 @ 1881.00 97.6 46.84224 ftlhr SURFACE TORQUE 5075 @ 1877.00 1263 @ 1939.00 4621.1 1263.72156 amps WEIGHT ON BIT 5 @ 1871.00 0 @ 1881.00 4.4 2.25045 Klbs ROTARY RPM 120 @ 1911.00 36 @ 1939.00 110.4 36.74281 RPM PUMP PRESSURE 1190 @ 1873.00 1012 @ 1939.00 1126.1 1012.85101 psi DRILLING MUD REPORT DEPTH: 1900 MW 9.0 VIS 56 PI/ 9 YP 30 FL 7.4 Gels 15/22/23 CL- 28000 FC 11 SOL 4.5 SD 0.25 OIL 0 MBL <1 pH 9.3 Ca+ 40 CCI MVI/D SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 73 @ 1874.00 6 @ 1881.00 24.7 TRIP GAS= NA CUTTING GAS 0 @ 1939.00 0 @ 1939.00 0.0 WIPER GAS= CHROMATOGRAPHYwpm) SURVEY= METHANE(C-1) 16070 @ 1874.00 1007 @ 1881.00 4972.9 CONNECTION GAS HIGH= 0 ETHANE(C-2) 0 @ 1939.00 0 @ 1939.00 0.0 AVG= 0 PROPANE(C-3) 0 @ 1939.00 0 @ 1939.00 0.0 CURRENT 0 BUTANE(C-4) 0 @ 1939.00 0 @ 1939.00 0.0 CURRENT BACKGROUND/AVG 18/25 PENTANE(C-5) 0 @ 1939.00 0 @ 1939.00 0.0 HYDROCARBONSHO~ NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 25% Conglomeratic Sand, 70% Sand and Sandstone; 5% Siltstone PRESENT LITHOLOGY 30% Conglomeratic Sand; 60% Sand and Sandstone; 10% Siltstone DAILY ACTIVITY Finish testing BOPs, test Casing, work on motor on drill floor, pick up 45 joints of drill pipe, and lay back 15 stands in derrick. Pick SUMMARY up BHA, run In hole with singles, tag cement at 1793', and drill to 1880'. Circulate hole clean and run leak off test, 18.0 ppg EMW. Drill ahead, rotating and sliding, from 1880' to 1939' Epoch Personel On Board= 4 Dally Cost ML: $2304 RW: $260 Report by: Brian O'Fallon . . . Marathon Oil Company DAILY WELLSITE REPORT g EPOCH Falls Creek #4 REPORT FOR Rowland Lawson DATE Jan 27, 2004 DEPTH 2989.00 PRESENT OPERATION= Drilling TIME 24:00:00 YESTERDAY 1939.00 24 Hour Footage 1050 CASING INFORMATION 133/8" @ 1840' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2839.00' 64.5 257.2 1997.4' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 2 12 1/4" HC MXC1 5044158 16c,3X18 1860 1129 13.65 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 280.2 @ 2515.00 9.4 @ 2512.00 86.9 19.88970 ftIhr SURFACE TORQUE 6753 @ 2550.00 8 @ 2541.00 3808.1 6149.37061 amps WEIGHT ON BIT 24 @ 2150.00 0 @ 2417.00 9.9 21.78367 Klbs ROTARY RPM 128 @ 2515.00 19 @ 2160.00 93.7 115.19402 RPM PUMP PRESSURE 1649 @ 2986.00 532 @ 2493.00 1309.6 1597.52234 psi DRILLING MUD REPORT DEPTH: 3000' MW 9.1 VIS 54 PV 11 yp 26 FL 7.0 Gels 15/19/21 CL- 31000 FC 11 SOL 5.5 SD 0.33 OIL 0 MBL 2.5 pH 9.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 322 @ 2828.00 8 @ 1939.00 65.9 TRIP GAS= CUTTING GAS 0 @ 2989.00 0 @ 2989.00 0.0 IMPER GAS= 113u CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) 64618 @ 2828.00 1495 @ 1939.00 13143.4 CONNECTION GAS HIGH= 0 ETHANE(C-2) 17 @ 2825.00 0 @ 2651.00 0.4 AVG= 0 PROPANE(C-3) 0 @ 2989.00 0 @ 2989.00 0.0 CURRENT 0 BUTANE(C-4) 0 @ 2989.00 0 @ 2989.00 0.0 CURRENT BACKGROUND/AVG 38/66 PENTANE(C-5) 0 @ 2989.00 0 @ 2989.00 0.0 HYDROCARBONSHO~ NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 20% Conglomeratic Sand and Conglomerate, 35% Sand and Sandstone, 20% Siltstone, 20% Claystone, 5% Coal PRESENT LITHOLOGY 60% Sand and Sandstone, 20% Siltstone, 20% Claystone DAILY ACTIVITY Drill from 1939' to 2895', mostly rotating, circulate hole clean, and wiper trip to 13318" casing shoe, backreaming out of hole due SUMMARY to numerous tight spots. Trip in and wash to bottom on last stand, 113 units of trip gas, and drill ahead, rotating, from 2895' to 2989' . Epoch Personel On Board= 4 Dally Cost ML: $2304 RW; $260 Report by: Brian O'Fallon . Marathon 011 Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Jan 28, 2004 DEPTH 3946.00 PRESENT OPERATION" Tripping In TIM E 24:00:00 YESTERDAY 2989.00 24 Hour Footage 957 CASiNG INFORMATION 13318· @ 1840' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3796.00' 52.4 255.0 2461.66' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 2 12 114· HC MXC1 5044158 16c,3X18 1860 2087 25.64 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 136.2 @ 2993.00 7.9 @ 3034.00 88.4 91.05469 ftIhr SURFACE TORQUE 8617 @ 3580.00 3 @ 3881.00 4845.3 5516.71094 amps WEIGHT ON BIT 27 @ 3883.00 0 @ 3279.00 12.8 5.50804 Klbs ROTARY RPM 121 @ 3860.00 0 @ 3776.00 100.3 114.07529 RPM PUMP PRESSURE 2036 @ 3580.00 1373 @ 3183.00 1758.9 1859.45752 psi DRILLING MUD REPORT DEPTH: 3947' MW 9.5 VIS 73 PV 14 yp 35 FL 7.0 Gels 15/30131 CL- 31000 FC 11 SOL 8.0 SD 0.33 OIL 0 MBL 6 pH 9.4 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 532 @ 3852.00 32 @ 2999.00 135.4 TRIP GAS= CUTTING GAS 0 @ 3946.00 0 @ 3946.00 0.0 \llnPER GAS= 109u(3947') CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) 88001 @ 3852.00 6395 @ 2999.00 26187.5 CONNECTION GAS HIGH= 350u(3851') ETHANE(C-2) 17 @ 3752.00 0 @ 3375.00 3.3 AVG= 35u PROPANE(C-3) 0 @ 3946.00 0 @ 3946.00 0.0 CURRENT 350u(3851') BUTANE(C-4) 0 @ 3946.00 0 @ 3946.00 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 3946.00 0 @ 3946.00 0.0 HYDROCARBONSHO~ 3775-3810': MAX382u1BGG160u; 3852-3862': MAX532u1BGG260u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 55% Sand and Sandstone; 30% Claystone, 10% Siltstone, 5% Coal PRESENT LITHOLOGY 70% Sand and Sandstone; 30% Claystone DAILY ACTIVITY Drill from 2989' to 3947', rotating to 3485', and sliding and rotating to drop angle from 3485' to 3947'. Wiper trip to shoe, SUMMARY backreaming due to multiple tight spots. Tripping in hole. . Epoch PersonelOn Board= 4 Dally Cost ML: $2304 RW: $260 Report by; Brian O'Fallon . Marathon Oil Co. DAll Y WEllSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Jan 29, 2004 DEPTH 4900.00 PRESENT OPERATION" Circulating at casing depth TIME 24:00:00 YESTERDAY 3946.00 24 Hour Footage 954 CASiNG INFORMATION 13318' @184O DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4845 24.90 256.20 3263.22 BIT INFORMATION INTERVAL CONDiTION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 2 121/4' HC MXC1 5044158 1&,3X18 1860 3040 41.46 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134.9 @ 4170.00 9.3 @ 4839.00 68.3 79.21620 ftIhr SURFACE TORQUE 7296 @ 4068.00 0 @ 4337.00 3621.4 5675.82520 amps WEIGHT ON BIT 26 @ 4065.00 0 @ 4710.00 13.5 21.14568 Klbs ROTARY RPM 127 @ 4463.00 0 @ 4450.00 76.0 119.86803 RPM PUMP PRESSURE 2327 @ 4838.00 976 @ 4271.00 2003.0 2094.86255 psi DRILLING MUD REPORT DEPTH: 4900 MW 9.6 VIS 58 PV 13 yp 33 FL 7.2 Gels 14/27/29 Cl- 31000 FC 11 SOL 8.5 SD 0.33 Oil 0 MBl 8.0 pH 9.5 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 328 @ 4222.00 45 @ 3966.00 131.4 TRIP GAS" CUTTING GAS 0 @ 4900.00 0 @ 4900.00 0.0 IMPER GAS= CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) 63717 @ 4222.00 9222 @ 3966.00 26944.3 CONNECTION GAS HIGH= 0 ETHANE(C-2) 57 @ 4462.00 0 @ 4023.00 25.3 AVG= 0 PROPANE(C-3) 3 @ 4086.00 0 @ 4059.00 0.1 CURRENT 0 BUTANE(C-4) 0 @ 4900.00 0 @ 4900.00 0.0 CURRENT BACKGROUND/AVG 146/131 PENTANE(C-5) 0 @ 4900.00 0 @ 4900.00 0.0 HYDROCARBONSHO~ 4210-4230': MAX32Su/BGG85u INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 15% Conglomeratic Sand and Conglomerate, 30% Sand and Sandstone, 40% Claystone, 10% Siltstone, 5% Coal PRESENT LITHOLOGY 30% Sand and Sandstone, 60% Claystone, 10% Coal DAilY ACTIVITY Finish tripping in hole and wash down last stand, 109 units of trip gas. Drill ahead, rotating and sliding, from 3946' to 4900', 9 SUMMARY 5IS' casing depth. Circulating bottoms up at casing depth. . . Epoch Personel On Board= 4 Daily Cost $2304 RW: $280 Report by: Brian O'Fallon . · Marathon Oil Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Jan 30, 2004 DEPTH 4900.00 PRESENT OPERATION= Run 9 5/8" Casing TIME 24:00:00 YESTERDAY 4900.00 24 Hour Footage 0 CASING INFORMATION 133/8'@ 1840' DEPTH iNCLINATION AZIMUTH VERTiCAL DEPTH SURVEY DATA 4845 24.90 256.20 3263.22 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS iN OUT FOOTAGE HOURS TIBlC PULLED 2 12 1/4" HC MXC1 5044158 16c,3X18 1860 4900 3040 41.46 Casing Depth DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 4900.00 NA @ 4900.00 NA NA ftIhr SURFACE TORQUE NA @ 4900.00 NA @ 4900.00 NA NA amps WEIGHT ON BIT NA @ 4900.00 NA @ 4900.00 NA NA Klbs ROTARY RPM NA @ 4900.00 NA @ 4900.00 NA NA RPM PUMP PRESSURE NA @ 4900.00 NA @ 4900.00 NA NA psi DRILLING MUD REPORT DEPTH: 4900 MW 9.6+ VIS 65 PI! 13 yp 31 FL 6.6 Gels 12/22/23 CL- 30000 FC 11 SOL 9.0 SD 0.33 OIL 0 MBL 10.0 pH 9.3 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HiGH LOW AVERAGE DITCH GAS 215 @ 4900.00 35 @ 4900.00 80 TRIP GAS= CUTTING GAS 0 @ 4900.00 0 @ 4900.00 NA WIPER GAS= 215u(4900') CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) NA @ 4900.00 NA @ 4900.00 NA CONNECTION GAS HIGH= NA ETHANE(C-2) NA @ 4900.00 NA @ 4900.00 NA AVG= NA PROPANE(C-3) NA @ 4900.00 NA @ 4900.00 NA CURRENT NA BUTANE(C-4) NA @ 4900.00 NA @ 4900.00 NA CURRENT BACKGROUND/AVG 35/60 PENTANE(C-5) NA @ 4900.00 NA @ 4900.00 NA HYDROCARBONSHO~ NA INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Circulate hole clean at least 4 bottoms up at casing depth. Pull out of hole 16 stands to 3373', backreamlng 4 through 11 due to SUMMARY tight spots. Trip to bottom and circulate hole clean for 2 hours, 215 units of trip gas down to 35 units before pumps off. Trip out of hole, lay down BHA, change rams and pull wear ring, and rig up and begin to run 9 5/8" casing. · Epoch Personel On Board= 4 Daily Cost ML: $2304 RW: $260 Report by: Brian O'Fallon · . Marathon Oil Company DAIL Y WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Jan 31, 2004 DEPTH 4900.00 PRESENT OPERATION" Begin testing BOPs TIME 24:00:00 YESTERDAY 4900.00 24 Hour Footage 0 CASING INFORMATION 133/8' @ 1840' 9518' @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4845 24.90 256.20 3263.22 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PUllED 2 12 1/4' HC MXC1 5044156 16c,3X18 1880 4900 3040 41.46 Casing Depth DRilliNG PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 4900.00 NA @ 4900.00 NA NA ftIhr SURFACE TORQUE NA @ 4900.00 NA @ 4900.00 NA NA amps VllEIGHT ON BIT NA @ 4900.00 NA @ 4900.00 NA NA Klbs ROTARY RPM NA @ 4900.00 NA @ 4900.00 NA NA RPM PUMP PRESSURE NA @ 4900.00 NA @ 4900.00 NA NA psi DRilLING MUD REPORT DEPTH: 4900 MW 9.5 VIS 57 Pt/ 12 yp 26 Fl 6.1 Gels 8116/19 Cl- 29000 FC 11 SOL 7.5 SD 0.25 Oil 0 MBl 7.0 pH 9.2 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH lOW AVERAGE DITCH GAS 75 @ 4900.00 12 @ 4900.00 25 TRIP GAS" CUTTING GAS 0 @ 4900.00 0 @ 4900.00 NA \I\IIPER GAS= 700(4900') CHROMATOGRAPHYwpm) SU RVEY.. METHANE(C-1) NA @ 4900.00 NA @ 4900.00 NA CONNECTION GAS HIGH= NA ETHANE(C-2) NA @ 4900.00 NA @ 4900.00 NA AVG= NA PROPANE(C-3) NA @ 4900.00 NA @ 4900.00 NA CURRENT NA BUTANE(C-4) NA @ 4900.00 NA @ 4900.00 NA CURRENT BACKGROUND/AVG 18125 PENTANE(C-5) NA @ 4900.00 NA @ 4900.00 NA HYDROCARBONSHO~ NA INTERVAL LlTHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAilY ACTIVITY Run total 117 joints of 9518' casing and hangar down to 4888 feet, and circulate bottoms up, maximum 75 units of trip gas. Rig SUMMARY up and cement casing, maximum 26 units of gas down to 18 units after cement. Work on top drive and nipple up BOPs while dumping mud and cleaning pits. Rig up to begin testing BOPs and begin mixing new mud. . Epoch Pensonel On Board" 4 Daily Cost Ml: $2304 RW: $260 Report by: Brian O'Fallon . . Marathon Oil Company DAIL Y WELLSITE REPORT g EPOCH Falls Creek'4 REPORT FOR Gene Anderson DATE Feb01, 2004 DEPTH 4920.00 PRESENT OPERATION= Begin Drilling TIME 24:00:00 YESTERDAY 4900.00 24 Hour Footage 20 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4845' 24.90 256.20 3263.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 8 1/2" HC HCM605 7104049 5X15 4900' 20 .23 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 118.1 @ 4907.00 14.4 @ 4901.00 94.1 95.89330 ftlhr SURFACE TORQUE 9898 @ 4915.00 8794 @ 4905.00 10120.1 9648.72363 amps IlVEIGHT ON BIT 6 @ 4904.00 0 @ 4906.00 3.1 2.77576 Klbs ROTARYRPM 52 @ 4918.00 49 @ 4905.00 54.9 52.57888 RPM PUMP PRESSURE 1266 @ 4904.00 934 @ 4906.00 1129.5 1066.51306 psi DRILLING MUD REPORT DEPTH: 4920' MW 9.0 VIS 55 PI/ 11 yp 23 FL 5.8 Gels 9/17/18 CL· 31000 FC <11 SOL 4.0 SD TR OIL MBL <1 pH 9.1 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 7 @ 4920.00 2 @ 4902.00 5.1 TRIP GAS= NA CUTTING GAS 0 @ 4920.00 0 @ 4920.00 0.0 IMPER GAS= CHROMATOGRAPHY~pm) SU RVEY= METHANE(C-1) 1263 @ 4919.00 485 @ 4902.00 984.6 CONNECTION GAS HIGH= NA ETHANE(C-2) 1 @ 4904.00 0 @ 4919.00 0.6 AVG= NA PROPANE(C-3) 0 @ 4920.00 0 @ 4920.00 0.0 CURRENT NA BUTANE(c-4) 0 @ 4920.00 0 @ 4920.00 0.0 CURRENT BACKGROUND/AVG 515 PENTANE(C-5) 0 @ 4920.00 0 @ 4920.00 0,0 HYDROCARBONSHO~ NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 20% Sand, 80% Cement PRESENT LITHOLOGY 20% Sand, 80% Cement DAILY ACTIVITY Continue mixing mud, and finish testing BOPs, pick up 90 joints of drill pipe, and stand back 30 stands in derrick. Test Casing, SUMMARY pick up BHA, and trip In hole to tag cement @ 4796'. Drill cement, float and shoe and 20' offormation down to 4920', Perform formation integrity test, 17.2 ppg EMW, displace hole with new mud, and begin to drill ahead at midnight. . Epoch Personel On Board= 4 Daily Cost ML: $2304 RW: $260 Report by: Brian O'Fallon . Marathon Oil Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Feb 02,2004 DEPTH 6177.00 PRESENT OPERATION= Drilling TIM E 24:00:00 YESTERDAY 4920.00 24 Hour Footage 1257 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6088.00' 24.9 252.80 4392.56' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/BlC PULLED 3 8 1/2" HC HCM605 7104049 5X15 4900' 1277' 10.74 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 221.4 @ 5673.00 19.6 @ 5013.00 136.0 188.66629 ftIhr SURFACE TORQUE 13264 @ 6115.00 0 @ 6159.00 9603.5 12482.67969 amps WEIGHT ON BIT 33 @ 5779.00 0.3 @ 4923.00 5.6 7.19703 KIbs ROTARYRPM 125 @ 5016.00 0 @ 8057.00 93.7 93.74783 RPM PUMP PRESSURE 2778 @ 6158.00 1216 @ 5238.00 1957.8 2433.17065 psi DRILLING MUD REPORT DEPTH: 6407 MW 9.5 VIS 61 PI! 12 yp 29 FL 6.6 Gels 10117/19 CL- 33000 FC 11 SOL 7.5 SD 0.33 OIL 0 MBL 2.5 pH 10.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1649 @ 5933.00 16 @ 4921.00 374.9 TRIP GAS= CUTTING GAS 0 @ 6177.00 0 @ 6177.00 0.0 WIPER GAS= 315u(5957ì CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 272612 @ 5933.00 2859 @ 4921.00 69544.9 CONNECTION GAS HIGH= 0 ETHANE(C-2) 358 @ 5933.00 0 @ 4921.00 81.3 AVG= 0 PROPANE(C-3) 54 @ 5842.00 0 @ 5340.00 11.6 CURRENT 0 BUTANE(C-4) 23 @ 5934.00 0 @ 5969.00 1.6 CURRENT BACKGROUND/AVG 295/375 PENTANE(C-5) 0 @ 6177.00 0 @ 6177.00 0.0 High gas 2+ BGG associated wi sand: 5015-3O:354u/170u; 5565-75:613u/300u; 5855- HYDROCARBONSHO~ 88:586u/330u; 5695-5705:586u/340u; 5820-80:1431 u/43Ou; 5920-50:1649u/630u;. 6025- 45:536u/280u. INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 35% Sand, 5% Conglomeratic Sand, 10% Siltstone, 40% Claystone, 10% Coal PRESENT LITHOLOGY 10% Sand, 50% Claystone, 40% Coal DAILY ACTIVITY Drill, mostly rotating, from 4920' to 5957', circulate two bottoms up and trip out to shoe, backreaming last two stands due tight SUMMARY spots. Cut and slip drill line and work on top drive. Trip to bottom washing down last stand, 315 units of trip gas. Drill ahead, mostly rotating, from 5957' to 6177'. . . Epoch Personel On Board= 4 Daily Cost ML: $2304 RW: $260. Report by: Brian O'Fallon . Marathon 011 Company DAIL Y WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Feb 03,2004 DEPTH 7131.00 PRESENT OPERATlON= Drilling TIM E 24:00:00 YESTERDAY 6177.00 24 Hour Footage 954 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7523' 24.0 255.5 5697.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 81/2" HC HCM605 7104049 5X15 4900' 2231' 22.24 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 936.0 @ 6664.00 4.7 @ 6453.00 158.2 221.37451 ftlhr SURFACE TORQUE 14330 @ 6556.00 0 @ 7117.00 9869.5 8964.83594 amps WEIGHT ON BIT 37 @ 6449.00 0 @ 7120.00 7.9 3.81531 Klbs ROTARY RPM 101 @ 6434.00 0 @ 7124.00 76.6 88.42509 RPM PUMP PRESSURE 2956 @ 6983.00 794 @ 6408.00 2577.4 2762.60132 psi DRILLING MUD REPORT DEPTH: 7500 MW 9.5 VIS 70 PV 17 YP 35 FL 4.8 Gels 12/18119 CL- 32000 FC 11 SOL 7.5 SD 0.33 OIL 0 MBL 4 pH 10.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1889 @ 7054.00 50 @ 6541.00 423.9 TRIP GAS= CUTTING GAS 0 @ 7131.00 0 @ 7131.00 0.0 WIPER GAS= 245u(6913') CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 569900 @ 7053.00 10250 @ 6541.00 81155.1 CONNECTION GAS HIGH= 0 ETHANE(C-2) 748 @ 7053.00 11 @ 6541.00 91.6 AVG= 0 PROPANE(C-3) 139 @ 7053.00 2 @ 6631.00 20.6 CURRENT 0 BUTANE(C-4) 14 @ 6960.00 0 @ 8875.00 0.3 CURRENT BACKGROUND/AVG 110/424 PENT AN E(C-5) 0 @ 7131.00 0 @ 7131.00 0.0 HYDROCARBONSHO~ Multiple shows twice background - see log INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 35% Sand and Sandstone, 20% Siltstone, 40% Claystone, 5% Coal PRESENT LITHOLOGY 20% Sand, 20% Siltstone, 60% Claystone DAILY ACTIVITY Drill from 6177' to 6913', wiper trip to 5856' with no problems, wash final stand to bottom. 245 units oftrip gas, and drill SUMMARY ahead. rotating and sliding. 6913' to 7131'. . . Epoch Personel On Board= 4 Dally Cost ML:$2304 RW:$260 Report by: Brian O'Fallon . Marathon Oil Company DAIL Y WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Gene Anderson DATE Feb 04, 2004 DEPTH 7910.00 PRESENT OPERATION= Trip out for wireline logs TIM E 24:00:00 YESTERDAY 7131.00 24 Hour Footage 779 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 25.1 254.7 5993.08' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 8 1/2" HC HCM605 7104049 5X15 4900 7910 3010 29.41 T.D. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 312.0 @ m6.00 10.4 @ 7669.00 174.3 122.13766 ftlhr SURFACE TORQUE 12422 @ 7788.00 0 @ 7319.00 9158.9 11094.12207 amps WEIGHT ON BIT 22 @ 7706.00 0 @ 7607.00 6.9 8.06559 Klbs ROTARYRPM 99 @ 7327.00 0 @ 7710.00 79.2 93.06963 RPM PUMP PRESSURE 3027 @ 7847.00 1191 @ 7607.00 2818.8 2930.28735 psi DRILLING MUD REPORT DEPTH: 7910' MW 9.5 VIS 88 PV 16 yp 27 FL 5.0 Gels 10117/19 CL- 30000 FC 11 SOL 7.5 SD 0.25 OIL 0 MBL 5.0 pH 9.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1297 @ 7642.00 48 @ 7607.00 348.3 TRIP GAS= CUTTING GAS 0 @ 7910.00 0 @ 7910.00 0.0 WIPER GAS= 405u(7910') CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 241290 @ 7642.00 9716 @ 7607.00 67696.5 CONNECTION GAS HIGH= 0 ETHANE(C-2) 267 @ 7851.00 13 @ 7680.00 70.1 AVG.. 0 PROPANE(C-3) 66 @ 7851.00 5 @ 7680.00 21.5 CURRENT 0 BUTANE(C-4) 23 @ 7642.00 0 @ 7698.00 1.3 CURRENT BACKGROUND/AVG 25/348 PENTANE(C-5) 0 @ 7910.00 0 @ 7910.00 0.0 HYDROCARBONSHO~ 7615-7670':MAX1297u/SOuBGG INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 40% Sand and Sandstone, 25% Siltstone, 25% Claystone, 10% Coal PRESENT LITHOLOGY 30% Sand and Sandstone, 20% Siltstone, 40% Claystone, 10% Coal DAILY ACTIVITY Drill ahead, rotating and sliding, from 7131' to 7606', and work on #2 pump. Drill ahead, rotating and sliding, from 7606' to 7910', SUMMARY total depth. Circulate two hours at 120 rpm to ctean hole, and short trip to 6818', backreaming through tight spots. Trip to bottom and circulate two hours at 120 rpm to ctean hole. Tripping out to shoe, some backreamlng above 6813' due to tight spots. . . Epoch PersonelOn Board= 4 Dally Cost ML:$2304 RW:$260 Report by: Brian O'Fallon . . . . Marathon 011 Company DAILY WELLSITE REPORT g EPOCH Falls Creek #4 REPORT FOR Brian O'Fallon DATE Feb 05.2004 DEPTH 7910.00 PRESENT OPERATION= Circulating on bottom TIME 24:00:00 YESTERDAY 7910.00 24 Hour Footage 0 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 25.1 254.7 5993.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 8 1/2" HC HCM605 7104049 5X15 4900 7910 3010 29.41 T.D. DRILLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 7910.00 NA @ 7910.00 NA NA ftIhr SURFACE TORQUE NA @ 7910.00 NA @ 7910.00 NA NA amps IlVEIGHT ON BIT NA @ 7910.00 NA @ 7910.00 NA NA Klbs ROTARY RPM NA @ 7910.00 NA @ 7910.00 NA NA RPM PUMP PRESSURE NA @ 7910.00 NA @ 7910.00 NA NA psi DRILLING MUD REPORT DEPTH: 7910 MW 9.65 VIS 74 PV 17 yp 27 Fl 5.2 Gels 9/17/19 CL- 28500 FC 11 SOL 8.0 SD 0.25 OIL 2.5 MBl 6.0 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 308 @ 7910.00 15 @ 7910.00 26 TRIP GAS= 308u(7910') CUTTING GAS 0 @ 7910.00 0 @ 7910.00 0 WIPER GAS= CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) NA @ 7910.00 NA @ 7910.00 NA CONNECTION GAS HIGH= ETHANE(C-2) NA @ 7910.00 NA @ 7910.00 NA AVG= NA PROPANE(C-3) NA @ 7910.00 NA @ 7910.00 NA CURRENT BUTANE(C-4) NA @ 7910.00 NA @ 7910.00 NA CURRENT BACKGROUND/AVG 17/26 PENT AN E(C-5) NA @ 7910.00 NA @ 7910.00 NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAilY Finish tripping out to shoe at 4888', backreamlng, and circulate one hour rotating 120 rpm to clean casing. Pull out of hole, lay ACTIVITY down BHA, and rig up Reeves for wire line logging. Complete wire line logging without problems, rig down Reeves, and trip In hole. SUMMARY Circulate 90 minutes rotating 90 rpm, 308 units of trip gas, and 90 minutas (until 1 am) rotating 80 rpm. gas to 17 units, cleaning hole for escaP,9 completion. Epoch Personel On Board= 2 Daily Cost Ml: $1694 RW:$260 Report by: Brian O'Fallon Marathon 011 Company DAIL Y WELLSITE REPORT ~ EPOCH Falls Creek #4 REPORT FOR Brian O'Fallon DATE Feb 06,2004 DEPTH 7910.00 PRESENT OPERATION- laying down drill pipe TIME 24:00:00 YESTERDAY 7910.00 24 Hour Footage 0 CASING INFORMATION 9518' @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 25.1 254.7 5993.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 3 8 1/2' HC HCM605 7104049 5X15 4900 7910 3010 29.41 T.D. DRilLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 7910.00 NA @ 7910.00 NA NA ftIhr SURFACE TORQUE NA @ 7910.00 NA @ 7910.00 NA NA amps WEIGHT ON BIT NA @ 7910.00 NA @ 7910.00 NA NA Klbs ROTARYRPM NA @ 7910.00 NA @ 7910.00 NA NA RPM PUMP PRESSURE NA @ 7910.00 NA @ 7910.00 NA NA psi DRilLING MUD REPORT DEPTH: 7910 MW 9.55 VIS 70 PV 15 yp 25 Fl 4.8 Gels 10116118 Cl- 29000 FC 11 SOL 7.5 SD 0.35 OIL 2.5 MBl 6.0 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 106 @ 7910.00 14 @ 7910.00 40 TRIP GAS.. 106u(7910') CUTTING GAS 0 @ 7910.00 0 @ 7910.00 0 WIPER GAS- CHROMATOGRAPHY~pm) SURVEY- METHANE(C-1) NA @ 7910.00 NA @ 7910.00 NA CONNECTION GAS HIGH= ETHANE(C-2) NA @ 7910.00 NA @ 7910.00 NA AVG= NA PROPANE(C-3) NA @ 7910.00 NA @ 7910.00 NA CURRENT BUTANE(c-4) NA @ 7910.00 NA @ 7910.00 NA CURRENT BACKGROUND/AVG 14/40 PENTANE(C-5) NA @ 7910.00 NA @ 7910.00 NA HYDROCARBONSHO~ NA INTERVAL LlTHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAilY ACTIVITY Finish çleaning hole, pull out to shoe, and wait on orders (9 hours). Run to bottom and çjrçulate hole çlean rotating 95 rpm, SUMMARY maximum 106 units trip gas. Pull out of hole to shoe. Pump slug and pull out of çasing and lay down 114 joints of drill pipe. . . Epoçh Personel On Board= 2 Daily Cost ML: $1694 RW:$260 Report by: Brian O'Fallon . . . . Marathon Oil Company DAILY WELLSITE REPORT ~ EPOCH Falls Creek #4 REPORT FOR BrIan O'Fallon DATE Feb 06,2004 DEPTH 7910.00 PRESENT OPERATION= Laying down drill pipe TIME 24:00:00 YESTERDAY 7910.00 24 Hour Footage 0 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 25.1 254.7 5993.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 81/2" HC HCM605 7104049 5X15 4900 7910 3010 29.41 T.D. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 7910.00 NA @ 7910.00 NA NA ftIhr SURFACE TORQUE NA @ 7910.00 NA @ 7910.00 NA NA amps WEIGHT ON BIT NA @ 7910.00 NA @ 7910.00 NA NA Klbs ROTARY RPM NA @ 7910.00 NA @ 7910.00 NA NA RPM PUMP PRESSURE NA @ 7910.00 NA @ 7910.00 NA NA psi DRILLING MUD REPORT DEPTH: 7910 MW 9.55 VIS 70 PV 15 yp 25 FL 4.8 Gels 10116/18 CL- 29000 FC 11 SOL 7.5 SD 0.35 OIL 2.5 MBL 6.0 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 106 @ 7910.00 14 @ 7910.00 40 TRIP GAS- 106u(7910? CUTTING GAS 0 @ 7910.00 0 @ 7910.00 0 WIPER GAS- CHROMATOGRAPHY~pm) SURVEY= METHANE(C-1) NA @ 7910.00 NA @ 7910.00 NA CONNECTION GAS HIGH= ETHANE(C-2) NA @ 7910.00 NA @ 7910.00 NA AVG= NA PROPANE(C-3) NA @ 7910.00 NA @ 7910.00 NA CURRENT BUTANE(C-4) NA @ 7910.00 NA @ 7910.00 NA CURRENT BACKGROUND/AVG 14/40 PENTANE(C-5) NA @ 7910.00 NA @ 7910.00 NA HYDROCARBONSHO~ NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Finish cleaning hole, pull out to shoe, and wait on orders (9 hours). Run to bottom and circulate hole clean rotating 95 rpm, SUMMARY maximum 106 units trip gas. Pull out of hole to shoe. Pump slug and pull out of casing and lay down 114 joints of drill pipe. Epoch Personel On Board= 2 Daily Cost ML: $1694 RW:$260 Report by: Brian O'Fallon . Marathon 011 Company DAILY WELLSITE REPORT U EPOCH Falls Creek #4 REPORT FOR Brian O'Fallon DATE Feb 07, 2004 DEPTH 7910.00 PRESENT OPERATION= Laying down drill pipe TIME 24:00:00 YESTERDAY 7910.00 24 Hour Footage 0 CASING INFORMATION 9518" @ 4888' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 25.1 254.7 5993.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBlC PULLED 3 8 1/2" HC HCM605 7104049 5X15 4900 7910 3010 29.41 T.D. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ 7910.00 NA @ 7910.00 NA NA ft/hr SURFACE TORQUE NA @ 7910.00 NA @ 7910.00 NA NA amps WEIGHT ON BIT NA @ 7910.00 NA @ 7910.00 NA NA Klbs ROTARY RPM NA @ 7910.00 NA @ 7910.00 NA NA RPM PUMP PRESSURE NA @ 7910.00 NA @ 7910.00 NA NA psi DRILLING MUD REPORT DEPTH: 7910 MW 9.55 VIS 72 PV 15 yp 26 FL 5.0 Gels 10116/18 CL· 29000 FC 11 SOL 8.0 SD 0.5 OIL 2.5 MBL 6.0 pH 9.1 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 5 @ 7910.00 1 @ 7910.00 2 TRIP GAS= NA CUTTING GAS 0 @ 7910.00 0 @ 7910.00 0 IMPER GAS= CHROMATOGRAPHY(ppm) SURVEY.. METHANE(C-1) NA @ 7910.00 NA @ 7910.00 NA CONNECTION GAS HIGH= ETHANE(C-2) NA @ 7910.00 NA @ 7910.00 NA AVG= NA PROPANE(C-3) NA @ 7910.00 NA @ 7910.00 NA CURRENT BUTANE(C-4) NA @ 7910.00 NA @ 7910.00 NA CURRENT BACKGROUND/AVG 2/2 PENTANE(C-5) NA @ 7910.00 NA @ 7910.00 NA HYDROCARBONSHO~ NA INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Run in hole with remaining (33 stands) drill pipe, and pull out and lay down remaining 114 joints of drill pipe. Lay down HWDP SUMMARY and bit, and rig up to run 3.5" escape completion. Run in hole with 3.5" tubing and all nine completion modules and the tank module. At 69 joints of tubing and 2650' at midnight. . Epoch Personel On Board= 2 Daily Cost ML: $1694 RW:$260 Report by: Brian O'Fallon .