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Home My WebLink About203-217From:Jacob Flora To:Brian Glasheen Subject:FW: Cementing Follow Up Report: Excape Control Lines Date:Wednesday, October 25, 2023 10:24:20 AM Boom From: Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent: Monday, July 12, 2021 2:20 PM To: bryan.mclellan@alaska.gov Cc: Taylor Wellman <twellman@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: Cementing Follow Up Report: Excape Control Lines Bryan, Below are the ¼” control lines we squeezed with the grease pump and Halliburton’s FineCem squeeze cement on the Excape IA squeezed wells we did in early January 2021. As you will notice the lines took a varying amount of cement. The 0.25” lines have an ID of 0.152” and capacity of 0.00094 gllons/ft. 2 gallons equates to 2127’ of control line. I plan on updating the WBDs and notating the cement volume pumped on each. Let me know if there is anything additional you would like to see here- Thanks, Jake PTD Well cement volume pumped date cemented 202-091 KBU 11-08Y 2 gallons on each line (7/2/2021) 205-141 KBU 41-06 1.5 gal red, 2 gal yellow and 2 gal green (7/2/2021) 204-209 KBU 42-06 2 gal yellow, 1.5 green and 1 gal red (7/2/2021) 200-179 KBU 44-06 1 gal red and 2 gal green (7/2/2021) 207-149 KBU 14-06Y 1.5 gal green and 0.5 gal red (7/2/2021) 203-217 KBU 23-07 1 gal red, .5 gal green and 1 gal yellow (7/2/2021) 203-025 BCU-11 2 gallons on each line (7/3/2021) 203-217 KBU 23-07 1 gal red, .5 gal green and 1 gal yellow (7/2/2021) 1. 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: N2 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: 4490; 5025; Total Depth measured 9,320 feet 6250; 6504 feet true vertical 7,965 feet 8,443 (fill) feet Effective Depth measured 4,463 feet N/A feet true vertical 3,772 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)N/A N/A 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:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 10,160psi 121' 1,394' 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi 10,540psi Casing Structural 20" 13-3/8" 9-5/*' Length 121' 1,395' 6,547' 9,268' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-322 16 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-217 50-133-20532-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 570 Kenai Beluga Unit (KBU) 23-07 N/A FEDA028142 6,547' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling Gas Pools 5.2, 4, 3, upper undefinedN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 3-1/2"9,268' 5,297' 7,913' WINJ WAG 0 Water-Bbl MD 121' 1,395' 0 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 9:59 am, Aug 03, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.03 09:47:39 -08'00' Taylor Wellman (2143) SFD 8/13/2021BJM 11/4/21 DSR-8/3/21 RBDMS HEW 8/5/2021 SFD 8/13/2021 Rig Start Date End Date 7/9/21 7/22/21 Sign in. Mobe to location. PTW, JSA and Simops w/Fox N2. Spot equipment and rig up lubrication and N2 hard lines. N2 told me they got a call at 9 am and said they were broke down and would be 1-1/2 hrs or so before they would be here. PT N2 lines and lubricator to 250 psi low and 3,500 psi high. Tubing pressure 850 psi. RIH w/2.75" CIBP, GPT tool and tie into Perf correlation log Perf 1 correlation pass revised dated 7/13/21. Did not see a fluid level. Run correlation log and send to town. Get ok to set plug at 4,490' w/850 psi on tubing. Spot and set plug. Lost about 80 lb of line tension. Pick up 30 ' and go back and tag plug. Good tag. POOH/tool good/good set. Bled well to 300 psi while POOH. RIH w/CCL, 2-1/2" x 30' (13.5') dump bailer filled w/17 ppg and tag plug 4,490' PU 15' and dump cement. Lost 85 lb. POOH. Good dump. RIH w/CCL, 2-1/2" x 30' (13.5) dump bailer filled w/17 ppg and dump cement on top of first dump at 4,476.5' Lost 85 lb. POOH. Good dump. TOC - 4,463'. Cement in Place at 1445 hrs. Rig down and WOC. TP - 300 psi. 07/09/2021- Friday 07/21/2021 - Wednesday 07/13/2021 - Tuesday Sign in. Mobe to location. Spot equip and rig up lubricator. PT to 250 psi low and 2,500 psi high. TP - 0 psi. Need to jump 100 psi of field gas. Jump 149.8 psi of field gas to well. RIH w/ 2-1/8" x 6' Shogun Spiral Strip Gun, 4 spf, 60 deg and tie into perf log. Run correlation log and send to town. Told to add 33'. Added 33' and sent back to town. Get ok to perf from 4,529' to 4,535'. Spotted and fired gun w/1,498 psi. After 5 min -166.1, psi, 10 min - 178.7 psi, and 15 min - 194.4 psi. POOH. All shots fired/ gun wet. RIH w/ 2-1/8" x 10' Shogun Spiral Strip Gun, 4 spf, 60 deg and tie into perf log. Run correlation log and send to town. Get ok to perforate from 4,519' to 4,529' w/244 psi and after fired 251 psi. After 5 min - 268.2 psi, 10 min - 281.7 psi and 15 min - 289.5 psi. POOH. All shots fired/Gun Wet. Rig down lubricator and equipment. Turn well over to field. Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. RIH w/ 2.75" OD CIBP and tie into CBL log. Run correlation log and send to town. Told to add 28'. Added 28' to log and sent it back. Get ok to set plug at 5,024.5'. Spotted plug and set plug w/100 psi on tubing at 5,024.5'. Lost 200 lbs line tension. PU 30' and go back down and tag plug. POOH. Setting tool looked good. Good set. RIH w/ 2-1/2" x 30' cement dump bailer loaded with of 17 ppg cement and tag plug with bottom of bailer at 5,025.5'. Dump cement on top of plug at (1300 hrs). POOH. Good dump. RIH w/ 2-1/2" x 30' cement dump bailer loaded with of 17 ppg cement (9.7 gals total) and stop with bottom of bailer 1' above top of first dump at 5,012'. Dump cement on top of first cement dump. CIP at 1400 hrs. Top of Cement 4,998'. POOH. Good dump. Fluid level is at 1,900'. Rig down lubricatorand equipment. Secure well. Wait on cement. Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 23-07 50-133-20532-00-00 203-217 dump cement on top of first dump at 4,476.5' go back and tag plug. Good tag. Get ok to perf from 4,529' to 4,535'. Spotted and fired gun w Dump cement on top of plug a Dump cement on top of first cement dump. Get ok to perforate from 4,519' to 4,529' TOC - 4,463' set plug w/100 psi on tubing at 5,024.5' All shots fired/G tag plug 4,490' PU 15' and dump cement. set plug at 4,490' w/850 psi on tubing. Spot and set plug. p of Cement 4,998'. Rig Start Date End Date 7/9/21 7/22/21 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 23-07 50-133-20532-00-00 203-217 07/22/2021 - Thursday Sign in. Mobe to location, rig back up, PT to 250 psi low and 2,500 psi high. TP - 345 psi. Samples cement samples were cured. RIH w/ 2-1/8" x 8' Shogun strip gun, 4 spf, 60 deg and tie into Plug log. Run correlation log and send to town. Town said on depth to perf Gun 1 from 4,216' to 4,224' and bleed pressure to 200 psi. Spotted and fired gun w/225 psi at 1024 hrs. After 5 min - 260 psi, 10 min - 274 psi and 15 min - 285 psi. POOH. All shots fired/Gun small amout moist sandy mud. Talked with town about bleeding well to see if we had gas. Bleed to 200 psi and shut in. Decision made to go ahead and perf A8. RIH w/ 2-1/8" X 10' Shogun strip gun, 4 spf, 60 deg and tie into Plug log. Run correlation log and send to town. Get ok to perf from 4,145' to 4,155'. Spot and fire gun w/257 psi. 5 min - 266 psi, 10 min - 270 psi and 15 min - 273 psi. POOH. . All shots fired/gun Dry. no mud. Rig down lubricator and turn well over to field. Finish rig down equipment. on depth to perf Gun 1 from 4,216' to 4,224' and bleed pressure to 200 psi. Spotted and fired gun w MITIA was not performed because the well did not return to production after the perfs did not find commercial gas. - bjm o perf from 4,145' to 4,155'. Spot and fire gun w Lease: State:Alaska Country: (TVD): Revised by:Donna Ambruz Last Revison Date: Completion Fluid: 4,145' - 6,388' 6º ĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: 6% KCL 7/28/2021 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 3,572' - 5,156' 3.5º / 100' @ 1,500' USA Excape System Details: Red control line: cemented w 1 gallon on 7/2/21 Green control line: cemented w 0.5 gallons on 7/2/21 Yellow control line: cemented w 1 gallon on 7/2/21 14 Conventional flappers - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #:203-217 API #:50-133-20532-00-00 Prop. Des:A - 028142 KB elevation:87' (21' AGL) WBS #: Latitude:60°27' 36.75" N Longitude:151°15' 54.42" W Spud:2/17/2004 TD:3/4/2004 Rig Released:3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 4,463' MD 3,772' TVD2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC 9-5/8 x 12-1/4 TOC @ 1496' (calculated w 25% washout) 3-1/2 x 9-5/8 TOC 1820' (12/30/20 CBL) 4490' CIBP w/ 27' of cmt, TOC @ 4463' (7-21-2021) 5025' CIBP w/ 27' of cmt, TOC @ 4998' (7-9-2021) 5176' PBTD 5247' Jet Cut Tubing Punch Holes: 5,275-78', 5,690-93', 5,900-03' 6250' CIBP w 35' cement top (12-11-2020) 6504' CIBP w cement top (06-06-2020) Perforations: MD TVD FT Sterling P3.A8 4,145' - 4,155' 3,572' - 3,582' 10 07/22/21 Open P3.A9 4,216' - 4,224' 3,615' - 3,623' 8 07/22/21 Open P4.B1A 4,519' - 4,535' 3,808' - 3,824' 16 07/13/21 Isolated P5.2_B5A 5,050' - 5,058' 4,151' - 4,166' 8 01/04/21 Isolated P5.2_B5A 5,050' - 5,060' 4,151' - 4,168' 10 01/08/21 Isolated Beluga UB 5B 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Isolated UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Isolated UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Isolated P3 P4 P5 Sterling P3.A8 4,145' - 4,155' 3,572' - 3,582' 10 07/22/21 Open P3.A9 4,216' - 4,224' 3,615' - 3,623' 8 07/22/21 Open Sterling ,, ,, p 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing N2: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,320'N/A Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 10,540 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 7,965'6,504'5,259'243 6504', 6250' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028142 203-217 50-133-20532-00-00 Kenai Beluga Unit (KBU) 23-7 Kenai Gas Field / Sterling Gas Pools 5.2, 4, 3, upper undefined Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 10,160 psi MD 5,750 psi 3,060 psi 3,450 psi 121' 1,394' 5,297' 121' 1,395' 7,913'3-1/2" 20" 13-3/8" 121' 9-5/8"6,547' 1,395' 9,268' Perforation Depth MD (ft): 6,547' See Attached Schematic 9,268' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 7/13/2021 N/A B No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:41 pm, Jun 30, 2021 321-322 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.30 14:19:18 -08'00' Taylor Wellman (2143) 10-404 BJM 6/30/21 MITIA to 1500 psi required within 10 days of returning the well to production. 20 AAC 25.055(a)(4) governs perforations in the Sterling Undefined Gas Pool * CO 510B X SFD 7/1/2021 DSR-6/30/21 *Spacing exception needed for perforations within the Sterling undefined gas pool. SFD 7/7/2021 dts 7/7/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.07 13:21:12 -08'00' RBDMS HEW 7/7/2021 Well Prognosis Well: KBU 23-07 Date: 05/26/2021 Well Name: KBU 23-07 API Number: 50-133-20532-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 07/13/2021 Rig: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-217 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Maximum Expected BHP: ~600psi @ 3572’ TVD (Based on offset data ) Max. Allowable Surface Pressure: ~243psi (Based on 0.1 psi/ft gas gradient) Brief Well Summary: KBU 23-07 drilled and completed in 2004 targeting the Beluga formation and completed as an Excape completion. The well came online making 5 MMCFD. The well went offline in 2012 due to sand production. A coil clean-out in 2014 was performed with little success. The well has cum’d just over 3.5 BCF and 1.5 MBW of water. In June 2020, there was failed attempt to add Upper Beluga perforations. The well was shot with 1340 psi and after 3 gun runs the tbg pressure dropped to below 1000 psi – all shots had fired and all guns were dry. The well would not sustain any flow. In January 2021, an IA squeeze was completed and the Sterling B5A was perforated. The well came online making just under 7 MMCFD. Since then it has cum’d 350 MMCF – until it recently sanded up and died. It was making ~300 MCFD and a few hundred bbls of water when it died. The plan is to march up hole to the next potential Sterling sand. Reserves for the B5A are not at risk here, as we are producing from 3 other wells in the field. Objective: The purpose of this work is to isolate the existing open perfs recomplete more sands uphole in the Sterling formation. Well Notes: - SL tagged sand @ 5039’ with a 2.5” bailer on 5/25/21 - Cement is good across all potential sends per CBL ran on 12/30/20 - MIT-IA Passed to 1500 psi on 9/2/20 Procedure E-line: 1. MIRU E-line, PT lubricator to 250 psi low and 2500 psi high. 2. RIH with 3-1/2” CIBP and set at ~5030’. 3. RIH and dump bail 25’ of cement on top of plug. a. Check samples 18-24 hours later. Slickline: 1. MIRU slickline, PT lubricator to 250 psi low and 2500 psi high. 2. Swab water off well down to 4800’. 3. RDMO slickline. E-line: 4. MIRU E-line, PT lubricator to 250 psi low and 2500 psi high. 5. Perforate the below zones from the bottom up with 2-1/8” Shogun Spiral Guns: Well Prognosis Well: KBU 23-07 Date: 05/26/2021 Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom PU_A6 ±3,877' ±3,896' 19' ±3,403' ±3,422' PU_A7 ±4,101' ±4,109' 8' ±3,544' ±3,552' P3_A8 ±4,145' ±4,155' 10' ±3,572' ±3,582' P3_A9 ±4,216' ±4,224' 8' ±3,615' ±3,623' P3_A10 ±4,271' ±4,296' 25' ±3,653' ±3,678' P3_A11 ±4,408' ±4,438' 30' ±3,737' ±3,767' P4_B1A ±4,519' ±4,535' 16' ±3,808' ±3,824' a. Discuss wellhead pressure with OE, anticipate wanting to hold 100 psi for initial shot. If necessary RU sales gas to pressure up well prior to perforating. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Sands that are not in the same pool will need to be isolated with a CIBP and 35’ of cement. 6. RD E-Line. 7. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Nitrogen (Contingency) 1. If Nitrogen is required to pressure up well prior to perforating or push fluid away: 2. MIRU Nitrogen Unit, review Nitrogen SOP, pressure well to desired perforating pressure. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 3-1/2” Casing Patch or set 3-1/2” CIBP above the zone and dump 25’ of cement on top of the plug. Attachments: Current Well Schematic Proposed Well Schematic Standard Well Procedure – N2 Operations PU_A7 MITIA to 1500 psi within 10 days after returning well to production. PU_A6 Sands that are not in the same pool will need to be isolated with a CIBP and 35’ of cement. Planned perforations between 3877' and 4109' MD within the Sterling undefined gas pool are removed from this application at the request of the operator. SFD 7/7/2021 Lease: State:Alaska Country: (TVD): 6% KCL 1/30/2021 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 4,151' - 5,156' 3.5º / 100' @ 1,500' USA Revised by:Donna Ambruz Last Revison Date: Completion Fluid: 5,050' - 6,388' 6º ĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Excape System Details - BHP monitoring line volume tank located from 6,584' -6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' located from 6, 6619'RKBModule 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #:203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60°27' 36.75" N Longitude: 151°15' 54.42" W Spud: 2/17/2004 TD: 3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls)of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 5,176' MD 4,241' TVD2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC 9-5/8 x 12-1/4 TOC @ 1496' (calculated w 25% washout) 3-1/2 x 9-5/8 TOC 1820' (12/30/20 CBL) 5176'PBTD 5247'Jet Cut Tubing Punch Holes: 5,275-78', 5,690-93', 5,900-03' 6250' CIBP w 35' cement top (12-11-2020) 6504' CIBP w cement top (06-06-2020) Perforations: MD TVD FT Sterling P5.2_B5A 5,050' - 5,058' 4,151' - 4,166' 8 01/04/21 Open P5.2_B5A 5,050' - 5,060' 4,151' - 4,168' 10 01/08/21 Open Beluga UB 5B 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Isolated UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Isolated UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Isolated Lease: State:Alaska Country: (TVD): Revised by:T. Hallett Last Revison Date: Completion Fluid: 5,050' - 6,388' 6ºĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: 6% KCL 5/25/2021 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 4,151' - 5,156' 3.5º / 100' @ 1,500' USA Excape System Details - BHP monitoring line volume tank located from 6,584' -6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #: 203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60° 27' 36.75" N Longitude: 151° 15' 54.42" W Spud: 2/17/2004 TD: 3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 5,176' MD 4,241' TVD2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 PROPOSED 9-5/8 x 12-1/4 TOC @ 1496' (calculated w 25% washout) 3-1/2 x 9-5/8 TOC 1820' (12/30/20 CBL) 5030' CIBP w/ 25' of cement on top 5247' Jet Cut Tubing Punch Holes: 5,275-78', 5,690-93', 5,900-03' 6250' CIBP w 35' cement top (12-11-2020) 6504' CIBP w cement top (06-06-2020) Perforations: MD TVD FT Sterling P5.2_B5A 5,050' - 5,058' 4,151' - 4,166' 8 01/04/21 Open P5.2_B5A 5,050' - 5,060' 4,151' - 4,168' 10 01/08/21 Open Beluga UB 5B 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Isolated UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Isolated UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Isolated STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 Davies, Stephen F (CED) From:Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent:Wednesday, July 7, 2021 10:33 AM To:Davies, Stephen F (CED) Subject:RE: [EXTERNAL] FW: KBU 23-7 (PTD 203-217; Sundry 321-322) - Question HiSteve, Hilcorpelectstoremovethetoptwoperforationzones:PU_A6(~3,877’Ͳ3,896’MD)andPU_A7(~4,101’Ͳ4,109’MD) fromthisSundryapplication.Wewillsubmitaspacingexceptionrequestinthefuturebutwouldliketogoafterthe eligiblesandsinthenearterm.Thankyouforcatchingthisonourapplication.Pleaseletmeknowifyouaregoodwith redliningthecurrentSundryorifyouwouldlikeanewsubmission. Thanks, Todd From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Wednesday,July7,20219:42AM To:ToddSidotiͲ(C)<Todd.Sidoti@hilcorp.com> Subject:RE:[EXTERNAL]FW:KBU23Ͳ7(PTD203Ͳ217;Sundry321Ͳ322)ͲQuestion Noworries.Ijustwanttoensurethatneitheroneofusforgetsaboutthisapplicationuntilthelastminute. From:ToddSidotiͲ(C)<Todd.Sidoti@hilcorp.com> Sent:Wednesday,July7,20218:59AM To:Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]FW:KBU23Ͳ7(PTD203Ͳ217;Sundry321Ͳ322)ͲQuestion HiSteve, SorryIwasoutlastweekbutwillworkonthistoday.Thankyouforfollowingup! Todd From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Wednesday,July7,20217:35AM To:ToddSidotiͲ(C)<Todd.Sidoti@hilcorp.com> Subject:[EXTERNAL]FW:KBU23Ͳ7(PTD203Ͳ217;Sundry321Ͳ322)ͲQuestion HiTodd, DidyoueverhavetimetolookatnearbywellstodeterminewhetherornotKBU23Ͳ7willneedaspacingexceptionif perforatedintheSterlingUndefinedGasPool? Thanks, SteveDavies AOGCC 2 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Davies,StephenF(CED) Sent:Thursday,July1,20217:37AM To:ToddSidotiͲ(C)<Todd.Sidoti@hilcorp.com> Cc:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov>;Boyer,DavidL(CED)<david.boyer2@alaska.gov> Subject:KBU23Ͳ7(PTD203Ͳ217;Sundry321Ͳ322)ͲQuestion Todd, I’mreviewingHilcorp’sSundryApplicationtoperforateKBU23Ͳ7.TwoofHilcorp’sproposedperforationintervalsinthis welllieabovetheSterlingGasPool3,whichisdefinedinConservationOrder510B.Sincethesetwoproposed perforationintervalswilllieinanundefinedgaspool,statewidewellspacingregulationsapply.AOGCC’srecords indicatenearbywellsKU21Ͳ7XandKU42Ͳ12beenperforatedinthissameundefinedgaspool.AreKU21Ͳ7XandKU42Ͳ 12,oranyotherwells,opentothisSterlingundefinedgaspoolwithinthesamegovernmentalsectionorwithin3,000 feetoftheproposedperforationsinKBU23Ͳ7?Ifso,aspacingexceptionwillberequiredbeforeperforatingthe SterlingundefinedgaspoolinKBU23Ͳ7. Thanksandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 1. 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: Install 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 9,320 feet 6250; 6504 feet true vertical 7,965 feet 8,443 (fill) feet Effective Depth measured 5,176 feet N/A feet true vertical 4,220 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)N/A N/A 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 0 Water-Bbl MD 121' 1,395' 336 Oil-Bbl measured true vertical Packer 3-1/2"9,268' 5,297' 7,913' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Up Tyonek Beluga GasN/A measured TVD Tubing Pressure 1000 Kenai Beluga Unit (KBU) 23-07 N/A FEDA028142 6,547' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-217 50-133-20532-00-00 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. 321-259 800 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 5,262 0 Representative Daily Average Production or Injection Data 121' 1,395' 6,547' 9,268' Conductor Surface Intermediate Production 10,540psi Casing Structural 20" 13-3/8" 9-5/*' Length 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 10,160psi 121' 1,394' 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 1:21 pm, Jun 18, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.18 11:51:38 -08'00' Taylor Wellman (2143) SFD 6/21/2021RBDMS HEW 6/22/2021 DSR-6/21/21BJM 10/11/21 Rig Start Date End Date 5/29/21 5/29/21 05/29/2021 - Saturday Rig up Capillary Truck. Install 3/8" Capillary string in well to 3,500'. Pickup weight recorded to be 1,100 lbs. Hang off Capillary string. RDMO Capillary truck. Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 23-07 50-133-20532-00-00 203-217 Lease: State:Alaska Country: (TVD): 6% KCL 6/2/2021 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 4,151' - 5,156' 3.5º / 100' @ 1,500' USA Revised by:Donna Ambruz Last Revison Date: Completion Fluid: 5,050' - 6,388' 6ºĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Excape System Details - BHP monitoring line volume tank located from 6,584' -6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #: 203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60° 27' 36.75" N Longitude: 151° 15' 54.42" W Spud: 2/17/2004 TD: 3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 5,176' MD 4,241' TVD2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC 9-5/8 x 12-1/4 TOC @ 1496' (calculated w 25% washout) 3-1/2 x 9-5/8 TOC 1820' (12/30/20 CBL) 5176' PBTD 5247' Jet Cut Tubing Punch Holes: 5,275-78', 5,690-93', 5,900-03' 6250' CIBP w 35' cement top (12-11-2020) 6504' CIBP w cement top (06-06-2020) Perforations: MD TVD FT Sterling P5.2_B5A 5,050' - 5,058' 4,151' - 4,166' 8 01/04/21 Open P5.2_B5A 5,050' - 5,060' 4,151' - 4,168' 10 01/08/21 Open Beluga UB 5B 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Isolated UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Isolated UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Isolated Capillary String Installed 05/29/21 3/8” Top Bottom MD 0’ 3,500’ TVD 0’ 3,170’ 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Add Capillary String 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,320'N/A Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 10,540 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 6/15/2021 3/8" Capillary tubing 9,268' Perforation Depth MD (ft): 6,547' See Attached Schematic 9,268' 7,913'3-1/2" 20" 13-3/8" 121' 9-5/8"6,547' 1,395' 3,060 psi 3,450 psi 121' 1,394' 5,297' 121' 1,395' N/A TVD Burst 3,000' (+/-) 10,160 psi MD 5,750 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028142 203-217 50-133-20532-00-00 Kenai Beluga Unit (KBU) 23-7 Kenai Gas Field / Sterling Gas Pools 5.2, 4, 3, upper undefined COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic tkramer@hilcorp.com 7,965'6,504'5,259'243 6504', 6250' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.27 16:20:30 -08'00' Taylor Wellman (2143) Yes 5/28/21 X Bryan McLellan BJM 5/28/21 Verbal approval to proceed granted. email attached. DLB 05/28/2021 DSR-5/28/21 10-404 dts 6/1/2021 6/1/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.06.01 12:02:41 -08'00' RBDMS HEW 6/2/2021 Well Prognosis Well: KBU 23-07 Date: 05/27/2021 Well Name: KBU 23-07 API Number: 50-133-20532-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 06/1/2021 Rig: N/A 10-403 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-217 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 10-403 Maximum Expected BHP: ~600psi @ 3572 TVD (Based on offset data ) Max. Allowable Surface Pressure: ~243psi (Based on 0.1 psi/ft gas gradient) Brief Well Summary: KBU 23-07 drilled and completed in 2004 targeting the Beluga formation and completed as an Excape completion. The well came online making 5 MMCFD. The well went offline in 2012 due to sand production. A coil clean-out in 2014 was performed with little success. The well over 3.5 BCF and 1.5 MBW of water. In June 2020, there was failed attempt to add Upper Beluga perforations. The well was shot with 1340 psi and after 3 gun runs the tbg pressure dropped to below 1000 psi all shots had fired and all guns were dry. The well would not sustain any flow. In January 2021, an IA squeeze was completed and the Sterling B5A was perforated. The until it recently sanded up and died. It was making ~300 MCFD and a few hundred bbls of water when it died. The plan is to march up hole to the next potential Sterling sand. Reserves for the B5A are not at risk here, as we are producing from 3 other wells in the field. Objective: The purpose of this work is run a capillary String to inject soap into the well. Well Notes: - SL tagged sand @ 5039 on 5/25/21 - Cement is good across all potential sends per CBL ran on 12/30/20 - MIT-IA Passed to 1500 psi on 9/2/20 Procedure Capillary Tubing Truck: 1. MIRU Cap string truck, PT packoff to 250 psi low and 2500 psi high. 2. RIH with 3/8 apillary tubing to 3,000 . 3. Hang off capillary line with packoff. 4. RDMO Cap String Truck. Attachments: Current Well Schematic Proposed Well Schematic 3/8" Cap. String @ 3,000' (+/-) Proposed 1 Carlisle, Samantha J (CED) From:McLellan, Bryan J (CED) Sent:Friday, May 28, 2021 11:29 AM To:Ted Kramer Cc:Donna Ambruz; Chmielowski, Jessie L C (CED) Subject:RE: 10-403 Submittal for KBU 23-07 Ted, Youhaveapprovaltoproceedwiththecapillarystringinstallation.YoushouldhavetheapprovedSundryonTuesday. Regards BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:TedKramer<tkramer@hilcorp.com> Sent:Friday,May28,20217:27AM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Cc:DonnaAmbruz<dambruz@hilcorp.com> Subject:FW:10Ͳ403SubmittalforKBU23Ͳ07 Bryan, IsubmittedthisSundrytoinstallaCapillarystringinKBU23Ͳ7yesterday.Thewellisstruggling(160to250mcfd)and wearetryingtokeepitproducinguntilwecangetaSundrysubmittedtoaddperforationstothewell.ToddSidotiis workingtheperfaddsundryanditshouldcomeovertoday.IamhopingtogetaverbalfromAOGCCtoinstallthiscap stringovertheweekend. 1. TheprocessplanwouldbeinstalltheCapstringthisweekendtokeepthewellonline. 2. SubmittheSundrytoaddperforationstoday. 3. Oncethesundryfortheperfaddisapproved,wewillpullthecapstringandaddtheperforations. Therefore,Hilcorprequestsaverbaltoinstallacapillarystringintheabovewell. Sincerely, TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 2 From:TedKramer Sent:Thursday,May27,20214:30PM To:aogcc.permitting@alaska.gov Cc:DonnaAmbruz<dambruz@hilcorp.com>;TomFouts<tfouts@hilcorp.com> Subject:10Ͳ403SubmittalforKBU23Ͳ07 Samantha, Pleaseprocesstheattached10Ͳ403submittalforKBU23Ͳ07PTD203Ͳ217. DonnaisonPTOtoday. TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. 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: Cement Pkr, N2 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 9,320 feet 6250; 6504 feet true vertical 7,965 feet 8,443 (fill) feet Effective Depth measured 5,176 feet N/A feet true vertical 4,220 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)N/A N/A 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:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 WINJ WAG 0 Water-Bbl MD 121' 1,395' 336 Oil-Bbl measured true vertical Packer 3-1/2"9,268' 5,297' 7,913' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Up Tyonek Beluga GasN/A measured TVD Tubing Pressure 1000 Kenai Beluga Unit (KBU) 23-07 N/A FEDA028142 6,547' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-217 50-133-20532-00-00 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. 320-505 800 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 5,262 0 Representative Daily Average Production or Injection Data 121' 1,395' 6,547' 9,268' Conductor Surface Intermediate Production 10,540psi Casing Structural 20" 13-3/8" 9-5/*' Length 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 10,160psi 121' 1,394' 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 9:11 am, Feb 16, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.02.16 09:01:43 -09'00' Taylor Wellman (2143) SFD 2/17/2021DSR-2/16/21BJM 3/31/21 RBDMS HEW 2/16/2021 Rig Start Date End Date 12/11/20 1/8/21 Arrive on location. Check in with WSM, walk down location, JSA with crew, fill out PTW. Begin rig up of Eline and hot oil truck. Hot oil pumped 33 bbls fresh water down tbg and gained psi. Continued rig up. Stab onto well. PT 250 low / 3,000 high. Open up to well and tools not falling, POOH to add more weight bar. Having issues bleeding off and valves frozen due to fresh water. Decided to bleed back psi and pump as much meth into the well as possible. After pumping meth valves clear. Bleed off and add 5' of weight bar. RIH w/ 3' of tbg puncher. Correlated to Expro CBL log dated April 11, 2004. Send log to town and confirm on depth and approved to shoot. SHOT TBG PUNCH HOLES @ 5,900' - 5,903' (3' above collar @ 5,906') (CCL to top shot = 8.8' / CCL stop depth @ 5,891.2') good indication of shot on wire and weight. Pre shot psi's (T/I/O) = 1,003# / 0 / 0. Post shot psi's (T/I/O)= 960#/ 0 / 0. Pressure up tbg to 1,200# and holding solid. IA still holding at zero. Called town and decided to pressure up to 3,000# and see what it does. POOH. OOH, bleed off and verified tbg punch shot. Install night cap on pump and sub. Pressure up tbg w/ pump truck to3,000# and still holding solid, IA remaining at zero. Cycle pressure by bleeding off and pressuring up a couple more time with no change. Call town and decision made to shoot holes approx. 200' higher. Rig up 2nd tbg puncher. RIH w/ 2nd (3') tbg puncher. Logged correlation pass to ensure on depth. Collar seen @ 5,687.5'. SHOT 2ND SET OF TBG PUNCH HOLE @ 5,690' - 5,693' (2.5' Below collar @ 5,687.5'') (CCL to top shot = 8.8 ' / CCL stop depth @ 5,681.2') good indication of shot on wire and weight. Pre shot psi's (T/I/O) = 1,280# / 0 / 0. Post shot psi's (T/I/O)= 1,100# and continuing to fall / 0 / 0. POOH. OOH and psi down to 1,000. Bleed off and confirmed good shots. Install night cap on pump and sub. Attempted to pump down tbg and take returns up IA but tbg still pressuring up to 3000# and holding solid, IA still holding at zero. Talked to town and decision made to run CBL tomorrow morning before making another TBG punch. Eline laid down equipment and left on location. Will return in AM to run CBL. Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 23-07 50-133-20532-00-00 203-217 12/11/2020 - Friday 12/12/2020 - Saturday Arrive on location. Check in w/ WSM, fill out permit, perform walk down and perform JSA. Rig up eline unit and equipment. Hook up 2.75" Legacy CIBP to tool string. PT surface equipment 250 low / 3,000 high. Start RIH. Performed correlation pass (tied into Expro CBL log dated April 11, 2004). Send to town. Shift +1' per town and approved to set. SET 2.75" CIBP @ 6,250'. Good indication of set. (CCL to mid element = 13' / CCL stop depth = 6237'). Tagged plug to confirm in place. POOH. OOH and confirmed good set on CIBP. Mix up cement and filled 30' of 2.5" bailer. RIH. Dumped load of cement on top of CIBP. Good indication of dumping. POOH. Out of the hole and bailer empty. Mix cement and filled 2nd bailer. RIH w/ 2nd bailer load of cement and dumped. Good indication of load dumping. POOH DUMPED TOTAL OF 35' OF CEMENT ON CIBP. ESTIMATED TOC @ 6215'. Out of the hole bleed off. Bailer empty. Lay down equipment on location and return in AM to punch tbg holes to establish circulation. Rig Start Date End Date 12/11/20 1/8/21 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 23-07 50-133-20532-00-00 203-217 RU Yellowjacket E-Line. RIH w 3.5" jet cutter head OD 2.5". Tie into CBL dated 12/13/2020. Pre cut: TBG: 500 psi, IA: 0 psi. Jet Cut tubing 5,274'. After cut TBG: 1,100psi, IA: 0 psi. POOH. RDMO. 12/13/2020 - Sunday Arrive on location. Check in with WSM, walk down location, JSA with crew, fill out PTW. Begin rig up of Eline. PT 250 low / 3,000 high. Start in hole w/ CBL logging tools. Logged CBL from 6,200' to 4,890'. Tied into Expro CBL dated April 11, 2004. Send correlation pass to Todd Sidoti and Jake Flora. POOH. OOH bleed off. Decision made to shoot tbg punch holes @ 5,275' - 5,278'. Lay down CBL and rig up tbg puncher. RIH w/ 3' of tbg puncher. SHOT 3rd SET OF TBG HOLES @ 5,275' - 5,278'. PSI started at (T/I/O) 680 / 0 / 0. Post shot still the same. POOH. (CCL to TS= 8.8' - CCL stop depth = 5,266.2'). OOH, bleed off off, lay down tools and confirmed good shot on tbg puncher. Rigged down equipment and move back to Pollard yard. Job complete. 12/27/2020 - Sunday Halliburton cementers arrive at KGF office. Conduct JSA and approve PTW. MIRU cement equipment. RU return line from IA to return tank. RU pump in sub with 1502 to tree cap. PT cement lines 1,000/4,000 psi. Pump 50 bbls freshwater down tubing taking returns out IA. Pump rate = 4.1 bpm @ 335 psi. Pump 20 bbls of 10.5 ppg spacer. Pump rate = 3.1 bpm, 130 psi. Pump 64 bbls of 12.0 ppg lead cement. Pump rate = 4.5 bpm @ 70 psi. Take sample and confirm cement weight. Pump 115 bbls of 15.3 ppg tail cement. Pump rate = 3.5 bpm @ 102 psi. Take sample and confirm cement weight. Start to see returns looking muddy rather than clean water. Shut down pump. Swap valves to launch 4" foam wiper ball. Pump freshwater displacement Pressure started to increase on displacement. Pressure increased to ~ 1,000 psi, then dropped off to ~ 750 psi with 42 bbls away. Pumped 45.5 bbls of displacement. Final tubing pressure = 745 psi. Shut in IA. Shut in swab and UMV. Clean up cement van and haul returns to G&I. 12/19/2020 - Saturday Rig Start Date End Date 12/11/20 1/8/21 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 23-07 50-133-20532-00-00 203-217 YellowJacket E-line arrive on location. Conduct JSA and approve PTW. MIRU. MU wireline valves and lubricator, MU Perforating BHA. PT lubricator 250/3,000 psi. Open well and RIH with 2-3/8" x 8', 60 deg phasing, 6 spf, perforating gun. WHP = 1,000 psi. Tag at 5,176' (corrected). Log up to 4,660' and send correlation data to town. Log is tough to interpret. Re-log from tag depth to 4,000'. Send correlation data to town. Add 29' to shift log down. Send data to town to confirm. Good to shoot. Pull perf gun into position, CCL to TS = 10.5'. Perforate 5,050' - 5,058'. Initial pressure = 972 psi, 5 min = 1106 psi, 10 min = 1150 psi, 15 min = 1,168 psi. POOH with Perf gun. Confirm shots fired. Laydown perforating string. RDMO. Hand well over to Production. 01/02/2021 - Saturday Petrospec coiled tubing arrive. Conduct JSA and approve PTW. Remove electrical and temporary piping from around wellhouse. Pick wellhouse with Peak crane and move off to side. Spot return tank and choke skid. Get a BX 154 x R39 flange from OSK to x-over from tree to BOP's. NU 4-1/16" dual combi BOP's and top of tree. Test blind/shear ram on BOP to 250/2,500 psi. Insert 1.75" test rod and test pipe/slip ram to 250/2,500 psi. Test Accumulator system. Close blind/shear ram and install night cap to secure well for the night. 01/03/2021 - Sunday Petrospec coiled tubing arrive and conduct JSA and approve PTW. MIRU Hilcorp Hot Oil Truck, Mag Tec water transport, MU Lubricator. MU YellowJacket 2.25" CTC and pull test to 25K. MU 2.13" DFCV, 2.125" BiDi Jars, 2.13" Disco, 2.13" Dual circ sub. Hot Oil truck unable to get burners lit. Troubleshoot with mechanic. Send transport, vac trucks to round trip hot water from Swanson river. RU water transport with hot water, load coil with 5 bbls of MeOH, followed by hot water. PT lubricator/stripper to 250/2,500 psi. PT BHA down to motor. MU 2.13" mud motor and 2.80" concave mill. Open well and RIH. Tag at 4,994' ctmd. Pick up weight = 19K. Pump at 1.2 bpm, CTP = 2,300 psi free spin. Mill easily until 5,105' ctmd, appears to be stringers of cement. Start to get motor stalls at 5,105', harder milling. Continue to mill until 5,157' ctmd. Stop milling at 5,157' ctmd. Drop 9/16" ball and open downhole circ sub. Fox Energy start pumping Nitrogen down coiled tubing taking returns to diffuser tank. Displace fluid from coil and wellbore to return tank. Trap 1200 psi on well. Close swab. Laydown milling BHA and lubricator sections. Close blind/shear ram and install night cap on top of BOPs. Will finish RD in the morning. 01/04/2021 - Monday 01/08/2021 - Friday AK E-line arrive on location. Conduct JSA and approve PTW. MIRU. OPS needed crane to remove wellhouse for slickline work. Crane back from ops, MU wireline valves and lubricator, MU Perforating BHA Gun #1, 10', 4spf, 60° phase 25 gram strip gun, Stab on well, PT WLV/lubricator 250/3,000 psi. Open well, WHP 1000, RIH. Tag @ 5,069' Corrected ELMD, pu no overpull, RIH tag again at 5,069' corrected ELMD, Log up to 4,000'. Download log, send to town for correction. On depth per (Ben Siks). RIH to light tag 5,069', pu to CCL Depth 5,031.2', CCL T/top shot 18.8, CCL T/bottom shot 28.8. Shoot P5.2_B5A 5,050'-5,060', log up 200' whp 1,020 psi initial, 5 min 1,020, 10 min 1,010. Tagged up, bleed down, pop off well, all shots fired. RDMO turn over to production. Control lines found to have pressure on them after perforating. Hilcorp will cement the control line and submit an additional 10-404. - BJM Lease: State:Alaska Country: (TVD): 6% KCL 1/30/2021 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 4,151' - 5,156' 3.5º / 100' @ 1,500' USA Revised by:Donna Ambruz Last Revison Date: Completion Fluid: 5,050' - 6,388' 6º ĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Excape System Details - BHP monitoring line volume tank located from 6,584' -6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' located from 6, 6619'RKBModule 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #:203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60°27' 36.75" N Longitude: 151°15' 54.42" W Spud: 2/17/2004 TD: 3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls)of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 5,176' MD 4,241' TVD2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC 9-5/8 x 12-1/4 TOC @ 1496' (calculated w 25% washout) 3-1/2 x 9-5/8 TOC 1820' (12/30/20 CBL) 5176'PBTD 5247'Jet Cut Tubing Punch Holes: 5,275-78', 5,690-93', 5,900-03' 6250' CIBP w 35' cement top (12-11-2020) 6504' CIBP w cement top (06-06-2020) Perforations: MD TVD FT Sterling P5.2_B5A 5,050' - 5,058' 4,151' - 4,166' 8 01/04/21 Open P5.2_B5A 5,050' - 5,060' 4,151' - 4,168' 10 01/08/21 Open Beluga UB 5B 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Isolated UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Isolated UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Isolated Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 23-7 (PTD 203-217) STRIP GUN 01/08/2021 Please include current contact information if different from above. Received by the AOGCC 01/22/2021 PTD: 2032170 E-Set: 34607 Abby Bell 01/25/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 23-07 (PTD 203-217) RCBL Memory Radial Cement Bond Log 12/30/2020 Please include current contact information if different from above. PTD: 2032170 E-Set: 34459 Received by the AOGCC 01/07/2021 **Resubmission** API Corrected Abby Bell 01/07/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 23-7 (PTD 203-217) FINAL Plug & Punch 12/11/2020 Please include current contact information if different from above. PTD: 2032170 E-Set: 34460 Received by the AOGCC 12/23/2020 Abby Bell 12/23/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 23-7 (PTD 203-217) FINAL CBL Cement Bond Log 12/13/2020 Please include current contact information if different from above. PTD: 2032170 E-Set: 34459 Received by the AOGCC 12/23/2020 Abby Bell 12/23/2020 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Nitrogen Ops: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,320'8,433' (fill) Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 10,540 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 12/15/2020 N/A 9,268' Perforation Depth MD (ft): 6,547' See Attached Schematic 9,268' 7,913'3-1/2" 20" 13-3/8" 121' 9-5/8"6,547' 1,395' 3,060 psi 3,450 psi 121' 1,394' 5,297' 121' 1,395' N/A TVD Burst N/A 10,160 psi MD 5,750 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028142 203-217 50-133-20532-00-00 Kenai Beluga Unit (KBU) 23-7 Kenai Gas Field / Sterling Gas Pools 5.2, 4, 3, upper undefined COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 7,965'6,504'5,259'1,325 psi 6,504' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:41 am, Nov 30, 2020 320-505 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.23 08:25:15 -09'00' Taylor Wellman Plug Perforations SFD 12/01/2020 cement packer/ gls 12/2/20 * CBL required post cement packer (forward to AOGCC for review) Perforate New Pool *Spacing exception required for any perforations shallower than Sterling 3 Gas Pool. * upper undefined * *See comment, below. DSR-11/30/2020 10-404 SFD 11/30/2020 Comm. 12/2/2020 dts 12/2/2020 JLC 12/2/2020 RBDMS HEW 12/2/2020 Well Prognosis Well: KBU 23-07 Date: 11/18/2020 Well Name:KBU 23-07 API Number:50-133-20532-00-00 Current Status:Shut In Gas Producer Leg:N/A Estimated Start Date:12/15/2020 Rig:E-Line Reg. Approval Req’d?Yes Date Reg.Approval Rec’vd: Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:203-217 First Call Engineer:Jake Flora (907) 777-8442 (720) 988-5375 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Max. Expected BHP:~1,740 psi @ 4,151’ TVD (Based on offset well data) Max. Potential Surface Pressure:~ 1,325 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Well Status KBU 23-07 is currently a shut-in Excape well that has been offline since April 2014. Brief Well Summary KBU 23-07 is an Excape completion which has had issues with water and sand production. In 12/2009 a cap string was installed in the well which helped it stay unloaded but eventually failed in its ability to deliver foamer to the perforations. In early 2012 the well finally died in the low pressure system and has yet to be resurrected. In June 2020, the original perforations were abandoned below a CIBP at 6504’, and three Upper Beluga perf intervals were added, however they produced no gas and the well has been shut in since. Objective The purpose of this work/sundry is to isolate the open perfs and perforate (8) intervals in the Sterling sands. Notes Regarding Wellbore Condition Min ID is 2.992’’ Casing Max Angle is 52.86 deg @ 3,261’ MD 5/30/2020 MITIA PASSED 6/06/2020 Set CIBP at 6504’. Perforate (3) upper beluga zones from 6278’ – 6388’ 9/02/2020 MITIA PASSED Procedure E-Line 1.RU E-Line, set CIBP at 6250’, dump 35 ft of cement on CIBP to abandon Upper Beluga perforations. 2. Pressure up on tubing to 250 psi, Perforate squeeze holes at 5950’, confirm communication, bleed pressure, RD E-Line. Fullbore Cement Job 3. RU Cementers. Establish circulation down the tubing and up the IA. 4. Mix and pump 228 bbls cement slurry. Drop wiper plug to 5500’ with 48 bbls water. 5. At 48 bbls stop displacing, record static pressure, there should be approximately 900 psi on tubing. 6. Shut in well with both master valves to trap pressure. 3.5" in IA .0639 bbl/ft 3 1/2" capacity = perforate (8) intervals in the Sterling sands. TOC at 2500 ft md .0087 bbl/ft 44 44 ? Plug Beluga sands CIBP to abandon Upper Beluga perforations. 3 1/2 x 9 5/8" = Well Prognosis Well: KBU 23-07 Date: 11/18/2020 7. WOC minimum of 3 days. 8. RU Slick-line, PT lubricator. Log memory CBL from TD to surface. Swab well down to 5000’. 9. RU E-line, PT lubricator. Perforate the below zones from the bottom up: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom PA Pool CO PU_A6 ±3,877' ±3,896' 19 ±3,403' ±3,422' Sterling KENAI, STERLING UPPER UNDF GAS Undefined PU_A7 ±4,101' ±4,109' 8 ±3,544' ±3,552' Sterling KENAI, STERLING 3 GAS Undefined P3_A8 ±4,145' ±4,155' 10 ±3,572' ±3,582' Sterling KENAI, STERLING 3 GAS CO 510A P3_A9 ±4,216' ±4,224' 8 ±3,615' ±3,623' Sterling KENAI, STERLING 3 GAS CO 510A P3_A10 ±4,271' ±4,296' 25 ±3,653' ±3,678' Sterling KENAI, STERLING 3 GAS CO 510A P3_A11 ±4,408' ±4,438' 30 ±3,737' ±3,767' Sterling KENAI, STERLING 3 GAS CO 510A P4_B1A ±4,519' ±4,535' 16 ±3,808' ±3,824' Sterling KENAI, STERLING 4 GAS CO 510A P5.2_B5A ±5,050' ±5,065' 15 ±4,151' ±4,166' Sterling KENAI, STERLING 5.2 GAS CO 510A a. Four distinct pools make up the proposed perforations. Each pool will need to be fully abandoned beneath a CIBP with cement top prior to moving up to the next pool above. b. Discuss wellhead pressure with OE. If necessary RU Nitrogen to pressure well prior to perforating. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. 10. POOH. Spacing exception required.* Upper Undefined Undefined Forward CBL to AOGCC for review before perforating. gls 12/2/20 SFD 12/01/2020 Undefined UPPER UNDF GAS * Any perforations shallower than the Sterling 3 Gas Pool will require a spacing exception under 20 AAC 25.055(a)(4). The proposed Sterling Upper Undefined Gas Pool perforations in this well will be in the same governmental section as perforations open to the same undefined gas pool in well KU 42-12, and they will also be within 3,000' of perforations open to the same undefined gas pool in wells KU 42-12 and KU 21-7X. SFD 12/01/2020 Well Prognosis Well: KBU 23-07 Date: 11/18/2020 11. RD E-Line. 12. Turn well over to production.(Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 3-1/2” Casing Patch or set 3-1/2” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure – N2 Operations Perfs TVD 5,415'-5,424'Isolated 6/6/20 5,479'-5,488'Isolated 6/6/20 5,618'-5,628'Isolated 6/6/20 5,654'-5,664'Isolated 6/6/20 5,702'-5,711'Isolated 6/6/20 5,802'-5,811'Isolated 6/6/20 5,937'-5,947'Isolated 6/6/20 6,001'-6,010'Isolated 6/6/20 6,133'-6,142'Isolated 6/6/20 6,229'-6,238'Isolated 6/6/20 6,551'-6,561'Isolated 6/6/20 6,799'-6,809'Isolated 6/6/20 7,311'-7,320'Isolated 6/6/20 7,387'-7,396'Isolated 6/6/20 7,829'-7,839'Isolated 6/6/20 Lease: State:Alaska Country: (TVD): Module 1 - 9,183'-9,193' Excape System Details Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Module 12 - 6,939'-6,949' - 15 Excape modules placed -Red control line fires top 8 modules -Green control line fires middle 6 modules -Yellow control line fires bottom 1 module - Ceramic flapper valves below each module Revised by:Jake Flora Last Revison Date: Completion Fluid: 6,278' - 6,388' 6ºĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: 6% KCL 11/17/2020 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,061' - 5,156' 3.5º / 100' @ 1,500' USA Tree cxn = 4-3/4" Otis 3-1/2" x 9-5/8" TOC @ 6,020' MD (CBL 4/11/04) Excape System Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #: 203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60° 27' 36.75" N Longitude: 151° 15' 54.42" W Spud: 2/17/2004 TD:3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 6,504' MD 5,259' TVD 2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC Perforation Detail: MD TVD FT UB 58 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Open UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Open UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Open Perfs TVD 5,415'-5,424'Isolated 6/6/20 5,479'-5,488'Isolated 6/6/20 5,618'-5,628'Isolated 6/6/20 5,654'-5,664'Isolated 6/6/20 5,702'-5,711'Isolated 6/6/20 5,802'-5,811'Isolated 6/6/20 5,937'-5,947'Isolated 6/6/20 6,001'-6,010'Isolated 6/6/20 6,133'-6,142'Isolated 6/6/20 6,229'-6,238'Isolated 6/6/20 6,551'-6,561'Isolated 6/6/20 6,799'-6,809'Isolated 6/6/20 7,311'-7,320'Isolated 6/6/20 7,387'-7,396'Isolated 6/6/20 7,829'-7,839'Isolated 6/6/20 Lease: State:Alaska Country: (TVD): Module 1 - 9,183'-9,193' Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Module 12 - 6,939'-6,949' Revised by:Jake Flora Last Revison Date: Completion Fluid: 6,278' - 6,388' 6ºĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: 6% KCL 11/5/2020 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,061' - 5,156' 3.5º / 100' @ 1,500' USA Tree cxn = 4-3/4" Otis 3-1/2" x 9-5/8" TOC @ 6,020' MD (CBL 4/11/04) Excape System Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #: 203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60° 27' 36.75" N Longitude: 151° 15' 54.42" W Spud: 2/17/2004 TD:3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 6,504' MD 5,259' TVD 2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 PROPOSED Planned Perforations: MD TVD FT PU_A6 3877' - 3896' 3403' - 3422' 19 Planned PU_A7 4101' - 4109' 3544' - 3552' 8' Planned P3_A8 4145' - 4155' 3572' - 3582' 10' Planned P3_A9 4216' - 4224' 3615' - 3623' 8' Planned P3_A10 4271' - 4296' 3653' - 3678' 25' Planned P3_A11 4408' - 4438' 3737' - 3767' 30' Planned P4_B1A 4519' - 4535' 3808' - 3824' 16' Planned P5.2_B5A 5050' - 5065' 4151' - 4166' 15' Planned Planned TOC 2500' Sterling Perfs 3877'-5065'Fullbore Cement Job wiper plug displaced to ~ 5500' squeeze holes ~ 5950' CIBP w cement top ~ 6250' Existing Perforations: MD TVD FT UB 58 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Open UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Open UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Open CIBP at 6250 ft STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. �3z►-7c Regg, James B (CED) From: Brooks, Phoebe L (CED) -�7 Sent: Thursday, September 17, 2020 11:52 AM To: Donna Ambruz Cc: Regg, James B (CED) Subject: RE: [EXTERNAL] FW: KBU 23-07 AOGCC 10-404 320-207 PTD 203-217 Submitted 06-26-20 MIT Supplement Attachments Attachments: MIT KBU 23-07 09-02-20 Revised.xlsx Donna, Attached is a revised report changing the gallons to bbls on the BBL Pump/Return. Please update your copy or let me know if you disagree. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information rnaV violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe brooksbalaska.gov. From: Donna Ambruz <dambruz@hilcorp.com> Sent: Monday, September 14, 2020 10:27 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: FW: [EXTERNAL] FW: KBU 23-07 AOGCC 10-404 320-207 PTD 203-217 Submitted 06-26-20 MIT Supplement Attachments Importance: High Per Phoebe Brooks request (and Ryan Rupert`s verification), please see the attached reports. Thank you. ` otma atnb ,-- operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct 907.777.8510 - Fax dambruz@hilcorp.com From: Brooks, Phoebe L (CED)[rrrailto:phoebe.brooks@alasl<a.Rov] Sent: Tuesday, September 8, 2020 9:46 AM To: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] FW: KBU 23-07 AOGCC 10-404 320-207 PTD 203-217 Submitted 06-26-20 MIT Supplement Attachments These reports need to be submitted in an Excel format so that we can import it into our database. Please resubmit the reports to the email addresses listed in the "Submit to" section of the form and have all fields filled out (PTD # 2032170, Type of Injection, Type of Test, Interval, Result, etc.; there are legends at the bottom of the form for reference). Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks4alaska.gov. From: Carlisle, Samantha J (CED) <samantha.carlisle 2alaska.gov> Sent: Tuesday, September 8, 2020 9:31 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks alaska.gov>; Regg, James B (CED) <iim.regg alaska.;;ov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gav> Subject: FW: KBU 23-07 AOGCC 10-404 320-207 PTD 203-217 Submitted 06-26-20 MIT Supplement Attachments From: Donna Ambruz <dambruz@hilcorp.com> Sent: Friday, September 4, 2020 10:15 AM To: AOGCC Permitting (CED sponsored) <aogcc.permittin @alaska.gov> Cc: Ryan Rupert <Ryan.Rupert hilcorp.com>; Taylor Wellman <twellman@hilcorp.corn>; Ted Kramer <tkramer hilcorp.com> Subject: KBU 23-07 AOGCC 10-404 320-207 PTD 203-217 Submitted 06-26-20 MIT Supplement Attachments FYI: Attached are the pre and post MIT -IA's from KBU 23-07 for AOGCC Sundry 320-207. Thank you. 29atma Qm.6,uvz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regoCrl4alaska.9ov, AOGCC.Insoectorsaalaska.goV; phoebe. brooksaalaska.gov OPERATOR: Hilcorp FIELD / UNIT / PAD: Kenai Beluga Unit KGF 14-6 DATE: 09/02/20 ' OPERATOR REP: Kevin Cassidy AOGCC REP: chris.wallace(Malaska. qoy Well KBU 23.07 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2032170 Type Inj N Tubing 100 100 100 100 100 100 Type Test P , Packer TVD 4996 BBL Pump 1.7 IA 80 1694 1684 1675 1670 1663 Interval 0 - Test psi 1500 BBL Return 1.4 OA 0 0 0 0 0 0 Result P Notes: Producer. Sundry #320-207 asked for MIT -IA before and after adperfs. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD I BBI -Pump I IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BEL Pump IA Interval Test psi BBL Return OA Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WTest Type Inj Tubing Type Test BBL Pu IA Interval BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G=Gas S = Slurry I = Industrial Wastewater N = Not Injecting TYPE TEST Codes INTERVAL Codes P = Pressure Test I = Initial Test O = Other (describe in Notes) 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT KBU 23-07 09-02-20 Revised Result Codes P = Pass F = Fail I = Inconclusive 1. 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: N2 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 9,320 feet 6,504 feet true vertical 7,965 feet 8,443 (fill) feet Effective Depth measured 6,504 feet N/A feet true vertical 5,259 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)N/A N/A 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 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 10,160psi 121' 1,394' 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi 10,540psi Casing Structural 20" 13-3/8" 9-5/*' Length 121' 1,395' 6,547' 9,268' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 20 Casing Pressure Liner 3 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-217 20 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-217 50-133-20532-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Kenai Beluga Unit (KBU) 23-07 N/A FEDA028142 6,547' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Up Tyonek Beluga GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 3-1/2"9,268' 5,297' 7,913' WINJ WAG 0 Water-Bbl MD 121' 1,395' 0 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 9:57 am, Jul 02, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.26 09:55:43 -08'00' Taylor Wellman 320-207 RBDMS HEW 6/29/2020 DSR-7/6/2020 Perforate SFD 7/2/2020 displace gls 9/18/20 Rig Start Date End Date E-ine 6/4/20 6/7/20 06/06/2020 - Saturday Sign in, mobe to location. PTW, JSA and SIMOPS with AKE-Line and SLB N2. Spot equip and rig up hard lines and lubricator. PT to 250 psi low and 4000 psi high. RIH w/GPT tool and found fluid level at 1,350'. Call town and discussed. Decision made to push fluid into perfs with N2. Pushed fluid into perfs below 6,500' with 1,750 psi . Ran correlation log and send to town. POOH to get a plug. Kept pressure around 1,700 psi. Used 850 gals of N2. RIH w/ 2.75" CIBP and tie into town log sent by Ben. Run correlation log and send to town. Get ok to set plug at 6,504' due to tubing collar being at 6,500'. Spot and set plug at 6,504' w/ 1,700 psi on tubing. Lost 50 lb of line tension when plug set. Pick up 30' and go back down and tag plug. POOH. Checked perf gun length and found that they built the guns off sundry instead of the quote. Decision was made to perforate in the morning after right guns were built. Rig for standby. 1,700 psi on tubing. 06/07/2020 - Sunday Sign in. Mobe to location. PTW and JSA. Rig back up lubricator. PT to 250 psi low and 3,500 psi high. TP - 1,750 psi. Fix a leak in hard lines. RIH w/ 2-3/8" x 10' Razor HC, 5 spf, 60 deg phase, tie into plug log and tag plug at 6,504'. Run correlation log and send to town. Get ok to perf from 6,378' to 6,388' with 1,340 psi on well. Spot and fire gun. After 5 min - 1,337 psi, 10 min - 1,333 psi and 15 min - 1,329 psi. POOH. All shots fired and gun was dry. RIH w/ 2-3/8" x 16' Razor HC, 5 spf, 60 deg phase, tie into plug log. Run correlation log and send to town. Get ok to perf from 6,316' to 6,332' with 1,280 psi on well. Spot and fire gun. After 5 min - 1,268 psi, 10 min - 1,252 psi and 15 min - 1,237 psi. POOH. All shots fired and gun was dry. RIH w/ 2-3/8" x 13' Razor HC, 5 spf, 60 deg phase, tie into plug log. Run correlation log and send to town. Get ok to perf from 6,278' to 6,291' with 1,022 psi on well. Spot and fire gun. After 5 min - 1,013 psi, 10 min - 1,001 psi and 15 min - 991 psi. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 23-07 50-133-20532-00-00 203-217 o perf from 6,278' to 6,291' w RIH w/GPT tool and found fluid level at 1,350'. Ca Get ok to perf from 6,378' to 6,388' w Get ok to set plug at 6,504' due t Decision made to push fluid into perfs with N2. Pushed fluid into perfs below 6,500' with 1,750 psi Get ok to perf from 6,316' to 6,332' with 1,280 psi on well. Perfs TVD 5,415'-5,424'Isolated 6/6/20 5,479'-5,488'Isolated 6/6/20 5,618'-5,628'Isolated 6/6/20 5,654'-5,664'Isolated 6/6/20 5,702'-5,711'Isolated 6/6/20 5,802'-5,811'Isolated 6/6/20 5,937'-5,947'Isolated 6/6/20 6,001'-6,010'Isolated 6/6/20 6,133'-6,142'Isolated 6/6/20 6,229'-6,238'Isolated 6/6/20 6,551'-6,561'Isolated 6/6/20 6,799'-6,809'Isolated 6/6/20 7,311'-7,320'Isolated 6/6/20 7,387'-7,396'Isolated 6/6/20 7,829'-7,839'Isolated 6/6/20 Lease: State:Alaska Country: (TVD): 6% KCL 6/17/2020 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,061' - 5,156' 3.5º / 100' @ 1,500' USA Revised by:Donna Ambruz Last Revison Date: Completion Fluid: 6,278' - 6,388' 6º ĺ 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Module 12 - 6,939'-6,949' - 15 Excape modules placed - Red control line fires top 8 modules - Green control line fires middle 6 modules - Yellow control line fires bottom 1 module - Ceramic flapper valves below each module Module 1 - 9,183'-9,193' Excape System Details Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Tree cxn = 4-3/4" Otis TOC (est.) @ 6,138' MD Excape System Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #:203-217 API #:50-133-20532-00-00 Prop. Des:A - 028142 KB elevation:87' (21' AGL) WBS #: Latitude:60°27' 36.75" N Longitude:151°15' 54.42" W Spud:2/17/2004 TD:3/4/2004 Rig Released:3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, TD 9,320' MD 7,965' TVD PBTD 6,504' MD 5,259' TVD 2/25/2014 - CT FCO to PBTD 9,230' UB 5B UB 6 UB 7A CIBP @ 6,504' 6/6/20 SCHEMATIC Perforation Detail: MD TVD FT UB 58 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Open UB 6 6,316' - 6,331' 5,094' - 5,107' 16 06/07/20 Open UB 7A 6,378' - 6,388' 5,147' - 5,156' 10 06/07/20 Open UB 58 6,278' - 6,291' 5,061' - 5,072' 19 06/07/20 Open UB 6 ,, 6,316' - 6,331' ,, 5,094' - 5,107' 16 p 06/07/20 Open UB 7A ,, 6,378' - 6,388' ,, 5,147' - 5,156' 10 p 06/07/20 Open New Perfs 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,320'8,433' (fill) Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 3,090 psi Production 10,540 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Christina Twogood Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: May 29th, 2020 N/A 9,268' Perforation Depth MD (ft): 6,547' See Attached Schematic 9,268' 7,913'3-1/2" 20" 13-3/8" 121' 9-5/8"6,547' 1,395' 3,060 psi 3,450 psi 121' 1,394' 5,297' 121' 1,395' N/A TVD Burst N/A 10,160 psi MD 5,750 psi Length Size N/A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028142 203-217 50-133-20532-00-00 Kenai Beluga Unit (KBU) 23-7 Kenai Gas Field / Up Tyonek Beluga Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic ctwogood@hilcorp.com 7,965'8,433'7,085'~ 1,098 psi N/A N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. N By Samantha Carlisle at 8:58 am, May 22, 2020 320-207 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.21 16:19:53 -08'00' Taylor Wellman Plug Perforations MIT-IA (3 1/2" x 9 5/8") before and after perforating to 1500 psi GAS SFD 5/22/2020 Perforate 10-404 N2 X DSR-5/26/2020gls 5/28/20Comm 5/28/2020 dts 5/28/2020 RBDMS HEW 6/4/2020 Well Prognosis Well: KBU 23-07 Date: 5/14/2020 Well Name: KBU 23-07 API Number: 50-133-20532-00-00 Current Status: Shut In Gas Producer Leg: N/A Estimated Start Date: May 29th, 2020 Rig: E-Line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-217 First Call Engineer: Christina Twogood (907) 777-8443 (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Current Max BHP: ~ 1,693 psi @ 5,415’ TVD (Based on offset well data) Max. Expected BHP: ~ 1,582 psi @ 5,061’ TVD (Based on actual reservoir conditions) Max. Potential Surface Pressure: ~ 1,076 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Brief Well Summary KBU 23-07 is an Excape completion which has had issues with water and sand production. In 12/2009 a cap string was installed in the well which helped it stay unloaded but eventually failed in its ability to deliver foamer to the perforations. In early 2012 the well finally died in the low pressure system and has yet to be resurrected. SL bailed the well down to 8487 on 10/25/2013 and attempted to swab it on line until 11/5/2013. Each swab pull was full of gas but the well was making too much water for the SL to keep dropping the FL. The well did show up to 410 psi on surface between swab runs. The purpose of this work/sundry is to isolate the open perfs and perforate (3) intervals in the Upper Beluga sands. Notes Regarding Wellbore Condition x Min ID is 2.992’’ Casing x Max Angle is 52.86 deg @ 3,261’ MD x Last Tag at 9,242’ RKB with 2” bailer on 5/5/2014 Safety Concerns x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). x Ensure all crews are aware of stop job authority. The purpose of this work/sundry is to isolate the open perfs and perforate (3) intervals in the Upper Beluga sands. NOTE: TOC in IA is close to top proposed perforation, MIT-IA before and after perfing to verify competent IA and cement packer. gls : Well Prognosis Well: KBU 23-07 Date: 5/14/2020 E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RIH with 3-1/2” CIBP and set at +6,500’. 5. RU perf guns. 6. RIH and perforate the following intervals: a. Pressure up well to 1,300 psi before perforating. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Up Tyonek / Beluga sands. 7. POOH. 8. RD E-Line. 9. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 3-1/2” Casing Patch or set 3-1/2” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure – N2 Operations Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Upper Beluga UB 5B ±6,278’ ±6,293’ ±5,061’ ±5,076’ ±15 Upper Beluga UB 6 ±6,316’ ±6,332’ ±5,094’ ±5,110’ ±16 Upper Beluga UB 7A ±6,378’ ±6,398’ ±5,147’ ±5,167’ ±20 plug perfs RIH with 3-1/2” CIBP and set at +6,500’. Upper Beluga UB 5B ±6,278’ ±6,293’ ±5,061’ ±5,076’ ±15 Upper Beluga UB 6 ±6,316’ ±6,332’ ±5,094’ ±5,110’ ±16 Upper Beluga UB 7A ±6,378’ ±6,398’ ±5,147’ ±5,167’ ±20 Perfs TVD 5,415'-5,424' 5,479'-5,488' 5,618'-5,628' 5,654'-5,664' 5,702'-5,711' 5,802'-5,811' 5,937'-5,947' 6,001'-6,010' 6,133'-6,142' 6,229'-6,238' 6,551'-6,561' 6,799'-6,809' 7,311'-7,320' 7,387'-7,396' 7,829'-7,839' Lease: State:Alaska Country: (TVD): 6% KCL 2/25/2014 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,415' - 7,839' 3.5º / 100' @ 1,500' USA Revised by:Tom Fouts Last Revison Date: Completion Fluid: 6,678' - 9,193' ĺ Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Module 12 - 6,939'-6,949' - 15 Excape modules placed - Red control line fires top 8 modules - Green control line fires middle 6 modules - Yellow control line fires bottom 1 module - Ceramic flapper valves below each module Module 1 - 9,183'-9,193' Excape System Details Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Tree cxn = 4-3/4" Otis TOC (est.) @ 6,138' MD Excape System Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Permit #:203-217 API #:50-133-20532-00-00 Prop. Des:A - 028142 KB elevation:87' (21' AGL) WBS #: Latitude:60° 27' 36.75" N Longitude:151° 15' 54.42" W Spud:2/17/2004 TD:3/4/2004 Rig Released:3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' TVD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, 45 sks (20 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, no cmt to surface TD 9,320' MD 7,965' TVD PBTD 9,230' MD 7,876' TVD 2/25/2014 - CT FCO to PBTD 9,230' EXPRO CBL log dated 4/11/2004 gls TOC IS ABOUT 6200 ft (Top perf is 6278') Perfs TVD 5,415'-5,424' 5,479'-5,488' 5,618'-5,628' 5,654'-5,664' 5,702'-5,711' 5,802'-5,811' 5,937'-5,947' 6,001'-6,010' 6,133'-6,142' 6,229'-6,238' 6,551'-6,561' 6,799'-6,809' 7,311'-7,320' 7,387'-7,396' 7,829'-7,839' Lease: State:Alaska Country: (TVD): Module 1 - 9,183'-9,193' Excape System Details Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Module 12 - 6,939'-6,949' - 15 Excape modules placed -Red control line fires top 8 modules -Green control line fires middle 6 modules -Yellow control line fires bottom 1 module - Ceramic flapper valves below each module Revised by:Christina Twogood Last Revison Date: Completion Fluid: 6,678' - 9,193' 6º → 25º Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: 6% KCL 5/27/2020 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,415' - 7,839' 3.5º / 100' @ 1,500' USA Tree cxn = 4-3/4" Otis TOC (est.) @ 6,138' MD Excape System Details -BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA Proposed KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Permit #:203-217 API #: 50-133-20532-00-00 Prop. Des: A - 028142 KB elevation: 87' (21' AGL) WBS #: Latitude: 60°27' 36.75" N Longitude: 151°15' 54.42" W Spud: 2/17/2004 TD: 3/4/2004 Rig Released: 3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' TVD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls)of 12.0 ppg, Type 1 cmt, 100% returns, 45 sks (20 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, no cmt to surface TD 9,320' MD 7,965' TVD PBTD 9,230' MD 7,876' TVD 2/25/2014 - CT FCO to PBTD 9,230' Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom UB 5B ±6,278' ±6,293'15'±5,061' ±5,076' UB 6 ±6,316' ±6,332'16'±5,094' ±5,110' UB 7A ±6,378' ±6,398'20'±5,147' ±5,167' UB 5B UB 6 plug set @ ±6,500' MD Perfs TVD 5,415'-5,424' 5,479'-5,488' 5,618'-5,628' 5,654'-5,664' 5,702'-5,711' 5,802'-5,811' 5,937'-5,947' 6,001'-6,010' 6,133'-6,142' 6,229'-6,238' 6,551'-6,561' 6,799'-6,809' 7,311'-7,320' 7,387'-7,396' 7,829'-7,839' Lease: State:Alaska Country: (TVD): 6% KCL 5/15/2020 Well Name & Number: County or Parish: Dated Completed:3/10/2004 Perforations (MD): Kenai Gas Field, A-028142 5,415' - 7,839' 3.5º / 100' @ 1,500' USA Revised by:Christina Twogood Last Revison Date: Completion Fluid: 6,678' - 9,193' ĺ Kenai Beluga Unit 23-7 Angle @ KOP and Depth: Kenai Peninsula Borough Angle/Perfs: Module 12 - 6,939'-6,949' - 15 Excape modules placed - Red control line fires top 8 modules - Green control line fires middle 6 modules - Yellow control line fires bottom 1 module - Ceramic flapper valves below each module Module 1 - 9,183'-9,193' Excape System Details Perfs MD (RKB): Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Tree cxn = 4-3/4" Otis TOC (est.) @ 6,138' MD Excape System Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Excape System Details: 14 Conventional flappers Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 15 - 6,697' Module 14 - 6,767' Module 13 - 6,919' Module 12 - 6,958' Module 11 - 7,009' Module 10 - 7,117' Module 9 - 7,262' Module 8 - 7,330' Module 7 - 7,470' Module 6 - 7,572' Module 5 - 7,909' Module 4 - 8,163' Module 3 - 8,680' Module 2 - 8,756' Module 1 - NA Proposed KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Permit #:203-217 API #:50-133-20532-00-00 Prop. Des:A - 028142 KB elevation:87' (21' AGL) WBS #: Latitude:60° 27' 36.75" N Longitude:151° 15' 54.42" W Spud:2/17/2004 TD:3/4/2004 Rig Released:3/9/2004 06:00 hrs PA #: Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' TVD 0' 121' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, 45 sks (20 bbls) to surface Intermediate Casing 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface Production Casing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, no cmt to surface TD 9,320' MD 7,965' TVD PBTD 9,230' MD 7,876' TVD 2/25/2014 - CT FCO to PBTD 9,230' Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom UB 5B ±6,278' ±6,293' 15' ±5,061' ±5,076' UB 6 ±6,316' ±6,332' 16' ±5,094' ±5,110' UB 7A ±6,378' ±6,398' 20' ±5,147' ±5,167' UB 5B UB 6 plug set @ ±6,500' MD new perfs arein95/8" overlap 6547 ft ±6,500' MD ar plug set @ pg @ perfs shown too deep... SUPERCEDED SUPERCEDED STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 Carlisle, Samantha J (CED) From:Christina Twogood - (C) <ctwogood@hilcorp.com> Sent:Wednesday, May 27, 2020 4:48 PM To:Schwartz, Guy L (CED) Cc:Ted Kramer; Donna Ambruz Subject:RE: [EXTERNAL] KBU 23-7 add perfs (PTD 203-217) Attachments:501332053200_KBU 23-07_CBL.PDF; KBU 23-07 PROPOSED 27May2020.pdf Follow Up Flag:Follow up Flag Status:Flagged Guy, PleasefindupdatedschematicandCBLattached. Additionally,thewellrecordsfromthedaytheCBLwasrunstatethattheTOCwasat6,020’.AMarathonschematic fromtheirlastworkovercampaignstatestheest.TOCis6,138’. Themoreconservativeofthesevalueshasbeenusedwithinthissundry. Thankyou, ChristinaTwogood OperationsEngineer KenaiAssetTeam,HilcorpAlaska 3800CenterpointDr.,Anchorage,AK99503 (w)907Ͳ777Ͳ8443 (c)907Ͳ378Ͳ7323 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Wednesday,May27,20209:28AM To:ChristinaTwogoodͲ(C)<ctwogood@hilcorp.com> Subject:[EXTERNAL]KBU23Ͳ7addperfs(PTD203Ͳ217) Christina, Foraddperfsintheoverlapofthe95/8”x3½”theCBLneedstobereviewedandMITͲIAto1500psibeforeandafter theperfsarerequired. Theschematicisnotcorrectinplacingthenewperfsbelowthe95/8”casingshoe.Canyouupdatetheschematicand resendtome. PullCBLandreverifyTOCandcementqualityintheperforationarea. Thanks! GuySchwartz Sr.PetroleumEngineer 2 AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). 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. ~ 03 - ~ 1 7 Well History File Identifier Organizing (done) D Two-sided 1111111111111I11111 D Rescan Needed 11111111111" 11I111 RESCAN t¢folor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date: R /~8/ Db I I D Other:: BY: ~ 151 ~ 11111111111111 "III Y11P Project Proofing BY: ~ Date rg 1:J.k / D b '3 x 30 =~ +& = TOTALPAGES~ I (Count does not include cover sheet) tJ C:::7 151 151 Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: JJ2:J.- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: ca I ~ ca / Ó b 11111111111111" III NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 151 V11 P NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111' "III BY: Maria Date: 151 Comments about this file: Quality Checked 11I1/1111111 1/11111 1 0/6/2005 Well History File Cover Page.doc oF ,§' \\V%% THE STATE • y 333 West Sevenlh Avenue GOVERNOR SLA N 1 AR\ELL Anchoroae, Alaska 99501-3572 �.* VW / 907.274 1233 SCANNED? MAY 0 92U1 Paul Chan d 3 7 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek Beluga Gas Pool, Kenai Beluga Unit 23-7 Sundry Number: 314-084 Dear Mr. Chan: 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, Cathy P. 'oerster Chair DATED this /81-s;day of February, 2014. Encl. • RECEIVED FEB 12 2014 ` /s 2.)17 I4 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ A0 - Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ I Other. CT Clean-out Q• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q • 203-217 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20532-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No D . Kenai Beluga Unit 23-7 • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDAO28142 Kenai Gas Field/Up Tyonek Beluga Gas• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,320' , 7,965' . 8,433' 7,085' N/A 8,433'(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 121' 20" 121' 121' 3,060psi 1,500psi Surface 1,395' 13-3/8" 1,395' 1,394' 3,450psi 1,950psi Intermediate 6,547' 9-5/8" 6,547' 5,297' 5,750psi 3,090psi Production 9,268' 3-1/2" 9,268' 7,913' 10,160psi 10,540psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/17/2014 Oil ❑ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan Email pchan@hilcorp.com Printed Name Paul CAI Title Operations Engineer Signature Phone 777-8333 Date 2/12/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: C-1-1;?/ 3 k`'(— 0 8 4-E Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: .- s----000 fi s';, /5 6 e (e-s/— RBDMS MAY u y 2014 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: ID - 4/Q / APPROVED BY Approved by: o. COMMISSIONER THE COMMISSION Date: R. -/e -4. 2./c,-.,,, ,,,,,o,..,,s,� ORIGINAL Qy A--, ,s, SubmitForm s1-) Form 10-403(Revised 10/2012) Approved application is valid for 12 m6nths from the date of approval. Attachments in Duplicate ,ti Hilcorp Alaska,LLC RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 FEB 1 2 2014 3800 Centerpoint Drive Suite 1400 (/� Anchorage,AK 99503 ® ®®GCC Phone: 907/777-8412 Fax: 907/777-8310 February 12, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Coiled Tubing Work at Kenai Gas Field Dear Commissioner Foerster: Attached for your review includes proposed Coiled Tubing work for the Kenai Gas Field. The coiled tubing work involves fill cleanouts with nitrogen. This work typically does not require sundry approval; however we are including a sundry application for the initial work proposed on Kenai Gas KBU 23-7 (PTD 203-217) to perform a fill cleanout on the well. Our company supervision will give notice during the initial rig up of the Coiled Tubing BOPE for the initial BOPE test. Below is a list of the wells and the proposed coiled tubing work: KBU 23-7 (PTD 203-217) Fill Cleanout KBU 24-6RD (PTD 206-013) Fill Cleanout KBU 34-6 (PTD 207-064) Fill Cleanout KBU 42-6 (PTD 204-209) Fill Cleanout Sundries for wells which may require a velocity string will be submitted individually. The two identified velocity string wells at this time are KTU 32-7 (PTD 200-023) and CLU-RD1 (PTD 203-129). If you need any additional information, you may contact me at 907-777-8333. Sincerely, HILCORP ALASKA C Paul Chan Operations Engineer pc Attachments Schwartz, Guy L (DOA) From: Tom Fouts <tfouts@hilcorp.com> Sent: Tuesday, February 11,2014 3:43 PM To: Schwartz, Guy L(DOA) Subject: RE:Coil Tubing Campaign for Kenai Gas and Cannery Loop Unit Field Guy, Thanks for the quick turnaround on this request. We will follow up as advised. Thanks again, Tom Fouts I Ops/Reg Tech Hilcorp Alaska, LLC tfouts(cphilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 From: Schwartz, Guy L(DOA) [mailto:g y.schwartz alaska.gov] Sent: Tuesday, February 11, 2014 2:36 PM To: Tom Fouts Cc: Larry Greenstein Subject: RE: Coil Tubing Campaign for Kenai Gas and Cannery Loop Unit Field Tom, Thanks for the info. Get me the Sundry to the first CT FCO. The two Velocity string wells will need sundries also. I would rather see sundries for now for all the velocity strings as they can be somewhat variable on how the string is landed and hung off. Make them simple and request waiver to the SSSV . Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Tom Fouts [mailto_tfouts a)hilcorp.com] Sent: Tuesday, February 11, 2014 9:18 AM To: Schwartz, Guy L(DOA) Cc: Larry Greenstein Subject: Coil Tubing Campaign for Kenai Gas and Cannery Loop Unit Field Guy, Hilcorp's South Kenai Team is planning a coil tubing cleanout campaign for 6 wells, 2 of which will also include the installation of a velocity string. This campaign will mainly consist of Kenai Gas Field wells with one additional well in the Cannery Loop Unit Field. 1 • • The preliminary planned order and activities are as follows: 1. KBU 23-7—CT cleanout 2. KBU 24-6RD—CT cleanout 3. KBU 42-6-CT Cleanout 4. KTU 32-7-CT cleanout and install velocity string 5. CLU 1RD-CT cleanout and install velocity string 6. KBU 34-6-CT cleanout Our request is to submit a 10-403 for the initial CT clean-out and then request a waiver for submitting 10-403's for the following CT tubing work for both fields. When referencing the sundry matrix sheet I provided yesterday,the velocity string installation should only require a 10-404. It is understood that this request does not omit the requirement of performing a BOP test for each well prior to operations. Please advise. Thanks, Tom Fouts j Ops/Reg Tech Hilcorp Alaska, LLC ttouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 2 s Marathon Alaska Production LLC Marathon Alaska Asset Team P.O. Box 1949 M .Alaska Production LLC Kenai, AK 99611 Telephone 9071283 -1371 Fax 907/283 -1350 December 21, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 DEC 3 2,. Alaska Oil &� �y laa Anc1?',:'hr Reference: 10 -404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 23 -7 7 Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for KBU 23 -7 well. This report covers the work performed to install a capillary string which is intended to assist with the fluid removal process. The string was installed on December 10, 2009 and set at a depth of 8,679' MD. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, D E 200 Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair WeIIL Plug Perforations L Stimulate Other d Installed Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver❑ Time Extension ❑ Capillary String Change Approved Program ❑ Operat. Shutdowr❑ Perforate ❑ Re-erNq er Suspended Well ❑ 2. Operator 4. Well Class Before Work: Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory ❑ 203 -217 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ k.API Number: Kenai Alaska, 99611 -1949 50- 133 - 20532 -00 -00 7. KB Elevation (ft): . Well Name and Number: 87' 21 AG L) Kenai Beluga Unit 23 -7 Property Designation: J0. Field /Pool(s): A - 028142 Kenai Gas Field / Beluga & Tyonek Pools 11, Present Well Condition Summary: Total Depth measured 9,320' feet Plugs (measured) NA true vertical 7,965' feet Junk (measured) NA Effective Depth measured 9,230' feet true vertical 7,876' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 121' 121' 3,060 psi 1,500 psi Surface 1,374' 13 -3/8" 1,395' 1,394' 3,450 psi 1,950 psi Intermediate 6,526' 9 -5/8" 6,547' 5,297' 6,870 psi 4,750 psi Production 9,247' 3 - 1/2" 9,268' 7,913' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 6,678' - 9,193' True Vertical depth: 5,415' - 7,839' Excape Tubing 3 -1/2" L -80 9,268' Tubing: (size, grade, and MD) Capillary String 3/8" 22 Stainless Ste el 8 "" , '' 6 ►► 79' Packers and SSSV (type and measured depth) NA N � jj E IVED 12. Stimulation or cement squeeze summary: DEU 2 '2� Intervals treated (measured): Installed ca14l9*at tG;Vi;@ a . ctltlfmissi;i ' Treatment descriptions including volumes used and final pressure: Anclu3i-Age 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,195 61 1 97 Subsequent to operation: 0 1,150 57 1 73 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development Service ❑ Daily Report of Well Operations X Vk. Well Status after work: Oil ❑ 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 -361 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician Signature Phone (907) 283 - 1371 Date December 21, 2009 Form 10 -404 Revised 04/2006 Submit Original Only 1.411111111F IW (6 Marathon Operations Summary Report by Job .0ilCompany Well Name: KENAI BELUGA UNIT 23 -7 Qtr /Qtr, Block, Sec, Town, Range Field Name License No. Statelprovinee Country 6006004 NO 11 W01 KENAI ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (H) KB- Ground D§Dnce (ft) Spud Date Rig Release Date 0.00 66.00 87.00 21.00 2!17,1004 Daily Operations Report Date: 12/11/2009 Job Category: R &M MAINTENANCE 24 Hr Summary Rig up coil unit, run cap string , rig down unit Ops Trouble Start Time End Time Dur her 0 sCode Activity Code Status Code Comment 07:30 08.15 0.75 SAFETY MTG AF PJSM- Review JSA's, assign job, review assignments, simultaneous operations, slips, trips, falls, overhead loads, pinch points, emergency contact numbers 283 -1305, let ring three times, no answer, call 911, muster point, emergency vehicle, buddy rule, three second rule, focus. Environmental issues, spills, hand injuries. Special review on hand injuries. 40% of safety incidents have been hand injuries. Focus on hand placement, use of gloves and overhead loads. 08:15 13:00 4.75 RURD COIL AF Rig up coiled tubing unit, crane truck, install extension and packoff on wellhead. Calibrate fluid control valve - 3500 #, perform pull test 500 #, test successful. Set injector head on well. Perform pressure test 200 # - test not successful. Rig down injector head and packoff to rebuild packoff which was leaking. Outside temperature is 6 deg. F. Leakage is proba bly due to cold. Will replace seals and retest.. Re -attch packoff to coil string. Perform pull test - 500# good. Re -set packoff and injector head onto wellhead extension. Perform pressure test 1500 # - test successful. 13:00 17:00 4.00 RUNPUL COIL AF Run 3/8" BJ DynaCoil into well. Hit bridge at 8690' MD. Brought tool up 8679' MD. Set capillary string at 8679' MD. Note: Digital counter failed, switched to mechanical counter. Spool length is supposed to be 9000'. Calculated length left on spool and there is approx. 140' more than odometer measurements less 9000'. BJ will determine accuracy of mechanical counter and we can move the coil accordingly if needed. 17:00 18:30 1.50 KURD COIL AF Rig down coiled tubing unit, set packoff, set back injector head onto cradle. Move off unit. 18:30 19:00 0.50 SECURE WELL AF Secure wellhead, attach warning signs to swab and upper / lower master valves to keep from closing valves and cutting capillary string. Re- install wellhouse. Leave location, turn in work permit. Go over well turn over form with #1 Operator. Sign and leave copies. www.peloton.com Report Printed: 12,11,2009 KBU 23 -7 Permit #: 203 -217 Pad 14 -6 M API #: 50 -133- 20532 -00 -00 317' FSL, 1,105' FWL, MARATHON Prop. Des: A - 028142 Sec. 6, T4N, R11 W, S.M. KB elevation: 87' (21' AGL) Conductor WBS #: 20" K -55 133 ppf Latitude: 60° 27' 36.75" IN Top Bottom Longitude: 151° 15' 54.42" W MD 0' 121' Spud: 2/17/2004 TVD TD: 3/4/2004 Surface Casing Rig Released: 3/912004 06:00 hrs 13 -3IS" K -55 68 ppf BTC PA #: I Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, Tree cxn = 4 -3/4" Otis I 45 sks (20 bbls) to surface Intermediate Casing TOC (est.) @ 6,138' MD 9 -518" L -80 40 ppf Mod BTC Top Bottom MD 0' 6,547' Excape System Details TVD 0' 5,297' - BHP monitoring line volume tank 12 -114" hole Cmt w/ 842 sks (352 bbls) of located from 6,584'- 6,619' RKB 13.5 ppg, class G cmt, no cmt to surface Production Tubing Excape System Details: 3 -112" L -80 9.3 ppf Mod EUE - Ceramic flapper valves below Top Bottom 8rd each module as follows: jll MD 0' 9,268' TVD 0' 7,544' 8 -112" hole Cmt w/ 1,147 sks (319 bbls) Flappers MD (RKB): Module 15 - 6,689' �� r of 15.8 ppg, class G cmt, 100% returns, r no cmt to surface Module 14 - 6,757' r Module 13 - 6,912' �4 P Module 12 - 6,951' Module 11 - 7,001' �� Excape System Details Module 10 - 7,109' 15 Excape modules placed Module 9- 7,252' Rea control line fires top 8 modules Module 8- 7,318' if, control line fires middle 6 modules Module 7- 7,461' Ill [ control line fires bottom 1 module Module 6- 7,563' ° Ceramic flapper valves below each module Module 5- 7,901' Module 4- 8,156' w hi [ Perfs MD (RKB): Module 3- 8,675' s r Module 15 - 6,678'- 6,688' Module 2- 8,750' pl t Module 14 - 6,748'- 6,758' Module 1 - NA Module 13 - 6,900'- 6,910' Module 12 - 6,939' - 6,949' Module 11 - 6,990'- 7,000' Module 10 - 7,098' - 7,108' Capillary Tubing (Installed 12/10/09) III Module 9- 7,243' - 7,253' 3/8" OD 2205 0.049" Module 8- 7,311'- 7,321' Stainless Steel Wall Thickness Module 7- 7,451'- 7,461' Module 6- 7,553'- 7,563' Top Bottom Module 5- 7,890' - 7,900' MD 0' 8,679' TVD 0' 7,328' Module 4- 8,144'- 8,154' Module 3- 8,661' - 8,671' Module 2- 8,738' - 8,747' TD PBTD Module 1 - 9,183'- 9,193' 9,320' MD 9,230' MD 7,965' TVD 7,876' TVD Well Name & Number: Kenai Beluga Unit 23 -7 Lease: Kenai Gas Field, A- 028142 County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,678' - 9,193' (TVD): 5,415'- 7,839' Angle /Perfs: 6° 25° Angle @ KOP and Depth: 3.5° / 100' @ 1,500' Dated Completed: 3/10/2004 Completion Fluid: 1 6% KCL Revised by: Kevin Skiba Last Revison Date: 12/21/2009 ^ ~ ~ ~ ,: ;, ~~~~ C ~ ~ ~ ~.~ ~ ~, r ~`4 ~ ~ ' V" " ~ ~ r~ ~ `~~-' ~ r ft ~ G~ ~ pr~@ ~ a ~ ~ h ~ ~ ,~ q ~ [[,~ tk /p~ ~~ ~ I N ~/ h~ y (~, ~ ~"' ~ ' F ~ ~S k ~~ ~' ~ ~~ {~ ~~ ~ ~ ~ Y `~ ~ n' ~ hr~/jg~i ~+ ~,pd SEAN PARNELL, GOVERNOR C.~~ ~, ~ k~~ 4-f'• ~~ ~ E~~7 t: ~~r~ ~.~ ~ -7 ~. Yr ~ ~~ ~~ ~ ~ ~~~~; p1. ~A~~~ p ~ c~.ast~-7~ ~IL ~D ~7 ~~ 333 W. 7th AVENUE, SUITE 100 COI~TSER'QATIOrT COMAIISSIOi~T d'~ ANCHORAGE, ALASKA 99501-3539 k ..'PHONE"""j9Q7)~J-'C~J3 ~' FAX (907) 276-7542 SVt~. iS~'Li~ S3lti.iu Re~atory ~omgliance ~I`echnician 1V~arathan Alaska Praductian LLC P.O. Box 1949 ~~~~~~ ~~J'' ~ ~~ ~~~'~ F~eraai, F~K 9961 I -1949 ~ ~a~ - ~ ~ I~e: I~enai ~as Fieic~, Beluga Ss iyanel~ ~ools, Kenai Belu~a LTnit 23-7 Suna~ ~iumber: 3~39-361 Dear Mr. Skiba: Enel~s~~ as the appr~v~~t App2icatian f~r Sun.dry Appr~val relating to the above referenced well. F2ease note the canditions of approval set out in the enciosed form. When providing n~tice for a representative of the Comriission to :~ntness any required test, contact the Commission's petroleum iieid inspector at (907) 659-3607 (pager). 1~~ pr~vided in 1~LS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause snown, 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 Qn a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this,~ day of Qctober, ~QJ~ Encl. u ~ Mara~thon MSftRAiHON Alaska Praductivn LL~ ~ ~thon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~JG'~ED October 23, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 23-7 Dear Mr. Aubert: ocr ~ ~ Z~o9 Alaska Oii ~ Gas Cons. Commission Anchorage Attached for your approval is the10-403 Application for Sundry Approvals for KBU 23-7 well. Marathon proposes to run a 3/8" capillary string in KBU 23-7 to assist with wellbore water removal. The target setting depth for this capillary string is 8,147' MD. / Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ ~ i ~~~Y~ ` Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File KJS a~ O~ t STATE OF ALASKA ~~0.2~'1 ~~~G~ Y ~~i~~~-- fo:1~~9 ALAS~IL AND GAS CONSERVATION C~MMI N ~~-~ ~~~~~~ wG~.. APPLICATION FOR SUNDRY APPROVALS io/tx~too4 2o p„4C 25.2so a~s~clrs~ ~lif i4~ G~s C0~I13. Commissi~n 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^ Waiv~~orage Other ^~ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ~ Time Extension Capillary String Change approved program ~ Pull Tubing [] Perforate New Pool ~ Re-enter Suspended Well ~ Install 2. Operator Name: Marathon Alaska Production LLC 4. Current Well Class: 5. Permit to Drill Number: Development ~ Exploratory ~ 203-217- 3. Address: p0 Box 1949 Stratigraphic ~ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20532-00-00 - 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: i E i S ^ ~ Kenai Beluga Unit 23-7~ ng xcept pac on Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A- 028142 87' (21' AGL) Kenai Gas Field / Beluga 8~ Tyonek Pools 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,320' _ 7,965' ' 9,230' ~ 7,876' - NA NA Casing Length Size MD ,~' ND Burst Collapse Structural Conductor 100' 20" 121' 121' 3,060 psi 7,500 psi Surface 1,374' 13-3/8" 1,395' 1,394' 3,450 psi 1,950 psi Intermediate 6,526' 9-5/8" 6,547' S,297' 6,870 psi 4,750 psi Production 9,247' 3-1/2" 9,268' 7,913' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,678' - 9,193' i 5,415' - 7,839' Excape 3-1/2" L-80 9,268' Capillary 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 0 BOP Sketch ~ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Novemb 9„~~09 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 Kevin J. Skiba Title Regulatory Compliance Technician Signature ` ' hone Date ~ (907) 283-1371 October 23, 2009 , COMMISSION USE ONLY ~/ Number: 3D y Conditions of a roval: Notif Commission so that a re rese tiv m witness Sund t , pp y p ry n a e ay Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~ ~ .~ 40 ~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~6/~ ~ . Form 10-403 Revised 06/2006 ~~~~ I n' ~~ ~%~ ~ ~ Submit in Duplicate (V • ~ M MARATHON KBU 23-7 Pad 14-6 Capstring Installation Procedure WBS: W0.09.20923.CAP.001 APPROVALS: Michael Dammeyer 10~19/09 Michael Dammeyer Ze~c D. ?f/alek 2l-det-09 Ken Walsh C. G. /6e~ >o~z/o9 Lyndon Ibele Author: Michael Dammeyer Latest Version Date: 10/1/09 Well Status: 9/29/09: Well flowing at 9.1 MM @ 148 psi into 56 psi LP system in the APL building. HistOry: • 10/18/09: PLT to mod 4(spinner quit at 8000') • 10/17/09: GR (GC?) 2.45" on 1.75" tool string. Tag 8181'(mod 4). Bump mods 12, 9, 8, 6. • 12/1/08: PT. Water 7350' at mod 8. • 12/1/08: GR 2.45" tag 7840'. Had to work through 12,9,8 mods. Well not flowing. • 2/8/05: DD Bailer 1.75" to 8738' over mod 2. Sample frac sand and coal. • 12/30/04: DD Bailer 2.00" to 8725'. Full bailer of sand. • 11/9/04: PLT memory. Tagged 4 places (7900/8315/8345/8530) and hung in one coming out. Gas from mods 4, 6-9, 15 mods, plus below. Mod 11 has water. • 11/8/04: DD Bailer 1.75". Tag in 5 mods and 8720'. • 11/7/04: DD Bailer 1.75". Got frac sand and coal pieces. • 11 /7/04: GC 2.00" tag at 6915'. Obiective: Install capillary string (3/8" 2205 0.049" WT) for delivering foamer to alleviate liquid loading. Procedure: Capstring Set Depth: Coil length: Max OD of BHA: Min ID of 3.5" tubing: 8,147' (6,802' TVD) 8,675' (From BC 19) 2.250" centralizer 2.992„ Disconnect power to wellhouse (call electrician). MI manlift. MI crane, arrange for crane operator. Move wellhouse. On truck: Coil, Well Head Adapter - Long w/ o-ring (WHA). Capstring Installation Procedure MDD Page 1 10/1 /2009 ~ ~ Paperwork: WBD, Sundry, Work Permit, Well Ops transfer sheet. 1. MIRU BJ Dyna-Coil unit. Place liner around wellhead/truck. Set outriggers & ground. Flag off location. 2. Shut swab valve, pull tree-cap flange, replace blanking plug w/ WHA (o-ring}. MU flange. Add snap ring. 3. Set Fluid Control Valve pressure to head pressure (so CICM surface line pressure equals BHP) _ (Setting TVD 6802')(0.433 psi/ft H20)(1.036 foamer SG) = 3050 psi. /" 4. Install valve on the surface end of tubing. 5. P/U Dyna-Coil injector with crane. Run 3/8" coil into injector chains. Adjust tubing straightener. 6. Run coil all the way through injector. Cut off non-straight tubing end (typically 5-15 ft). 7. Run the coil through BJ pack-off (hold pack-off with support pin). 8. Attach BHA. "Pull tesY' BHA to 500 Ibs to verify ferrule is secure. Pull support pin. Gage BHA. 9. Lift injector. Thread pack-off into 2-7/8" female WHA (use teflon & lube). Hold WHA w/ tong/wrench. 10. Lower injector head carefully on to the pack-off (line up slot with the pack-off's'/<" x 4" nipple). 11. Attach hydraulic hoses to hydraulic rams. Attach MeOH hose to inlet valve. Insert snubbing guides. 12. Wrap wellhead and packoff with absorbents to catch drips. ------------------- revisit JSA ---------------------- 13. Pressure hydraulic rams (top seal, '/" nipple) on pack-off to 3000 psi. 14. Pressure test well head adapter using MeOH at 1.5x SIWHP. Watch for leaks carefully. Release pressure. 15. Open swab valve. Watch for leaks at pack-off. 16. Adjust hydraulic rams (top seal) pressure to minimum level (100-500 psi). Ensure Rattiguns are open. 17. Set depth counter. RIH 100 fpm (lube/guide coil as needed), tag bottom, pull up to set depth of 8147'. '" ------------------- revisit JSA ---------------------- 18. Set slips. Set Rattiguns. Release pressure on upper hydraulic seal (to protect operator). Watch for leaks. 19. Lift injector head off and away from well. 20. Pressure hydraulic rams (top seal) on pack-off to 2500 psi. Close needle valve and insert hydraulic plug. 21. Pull tubing excess through injector, or split injector head to remove tubing if over 500' of excess coil. 22. Connect tubing to Swagelok injection manifold (valve, gauge, filter, gauge, valve) to CICM line. 23. Lockout Swab, Upper & Lower Master valves with yellow chain and signs. See photos for examples. 24. Pump foamer into capstring until fluid packed (if not already full). 25. Hookup injection line to CICM. Start foamer at 1 qpd. 26. Replace well house. Be careful of the tubing "bend" as it goes back inside if it extends through the roof. 27. RDMO. Cleanup site. Sign-out. Fill out Well Ops Transfer Sheet. ~ PLT 10/18/09: \\kpfrs600.kqf.moc.com\kqfshrWlaska Wells Group\PT Survevs\KGF\KBU 23-07 PLT 10-18- 09. pdf PLT 11/08/04: \\kqfrs600.kqf.moc.com\kafshrWlaska Wells Group\PT Survevs\KGF\KBU 23-07 PLT 11-08- 04.doc WBD: \\kqfrs600.kaf.moc.com\kafshrWlaska Wellbore Diaarams\KBU 23-07 WBD 09-28-09.x1s Pictures: \\kafrs600.kaf.moc.com\kafshr~Alaska Wells Group\Procedures\Dvna-Coil\Capstrinq Installation Pictures.doc Considerations Instructions and Planninp: • If there are any restrictions in the well, or have measurable overpull coming out of the hole with a capstring, pull out slowly to avoid severing a potentially damaged capstring (see BC 19 10/16/09). • Ensure the fluid control valve setting pressure is recorded in WeIlView. • If setting depth is uncertain, ensure the string is set too high rather than low. • Always tag before setting the capstring, or pulling the capstring OOH - this way, fill can be quantified over the capstring use. Capstring Installation Procedure MDD Page 2 10/1 /2009 . . ~s 203-217 50-133-20532-00-00 A - 028142 n: 87' (21' AGL) 60° 27' 36.75" N 151°15'54.42"W 2/17/2004 3/4/2004 : 3/9/2004 06:00 hrs TOC (est.) - ???' Excape Svstem Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB Ceramic flapper valves below each module as follows: Module 15 - 6,689' Module 14 - 6,757' Module 13 - 6,912' Module 12 - 6,951' Module 11 - 7,001' Module 10 - 7,109' Module 9 - 7,252' Module 8 - 7,318' Module 7 - 7,461' Module 6 - 7,563' Module 5 - 7,901' Module 4 - 8,156' Module 3 - 8,675' Module 2 - 8,750' Module 1 - NA Taqaed @ 8,162' MD (10l18/09) 1" KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11 W, S.M. .- .~ ~ ~ TD PBTD 9,320' MD 9,230' MD 7,965' TVD 7,876' TVD ~ M ~u-~rNON Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' ND 0' 121' 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' TVD 0' 1,394' 16" hole Cmt wl 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100°/ retums, 45 sks (20 bbls) to surFace Intermediate Casinq 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' TVD 0' S,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt wl 1,147 sks (319 bbis) of 15.8 ppg, class G cmt, 100% returns, no cmt to surFace - 15 Excape modules placed - Red control line fires top 8 modules -:~reer. control line fires middle 6 modules - control line fires bottom 1 module - Ceramic flapper valves below each module Perts MD (RKB): Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Module 12 - 6,939'-6,949' Module 11 - 6,990'-7,000' Module 10 - 7,098'-7,108' Module 9 - 7,243'-7,253' Module 8 - 7,311'-7,321' Module 7 - 7,451'-7,461' Module 6 - 7,553'-7,563' Module 5 - 7,890'-7,900' Module 4 - 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 1 - 9,183'-9,193' Well Name & Number: Kenai Beluga Unit 23-7 Lease: Kenai Gas Field, A-028142 County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,678' - 9,193' (TVD): 5,415' - 7,839' Angie/Perfs: 6° ~ 25° Angle @ KOP and Depth: 3.5° / 100' @ 1,500' Dated Completed: 3/10/2004 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 10/22/2009 • ~ IVlarathan NiARdiHON Alaska Praductian LLC ~ M~hon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~GCG~ Y GC~ October 8, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 23-7 Dear Mr. Aubert: OCT 1 2 2009 Alsska Oil & Gas Cons. Cor~misxion Anchorage ~,a3~~ ~ 7 ~<< -, ~:: _ ` ':Ji..~~ Attached for your records is the10-404 Report of Sundry Well Operations for KBU 23-7 well. The AOGCC provided approval for the addition of 58' of perForations under Sundry # 308-351. Marathon no longer intends to perform this activity and is closing out this sundry as a Non-Work activity. Other wells in this program experienced reduced production when perforated, which was caused by additional water infiltrating the wellbore. This decision is intended to minimize the risk of loosing crucial production while entering the high demand season. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, . .,2~.. . ` 1~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~ECE~vE,~ 0 C T 1 ~~'~~°O'+ Al~ska Oil & Gas Cons. Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ tIC ork of Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ^ perforation Change Approved Program ~ Operat. Shutdown ~ Perforate ^ Re-enter Suspended Well ~ additions 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Per to Drill Number: ~ ame: Development ^~ Exploratory^ 203-217 3. Address: p0 BoX 1949 Stratigraphic ~ Service ^ 6. l~PI Number. Kenai Alaska, 99611-1949 ~ 50-133-20532-00-00 7. KB Elevation (f#1: "\ 9. Well Name nd Number: , 87' (21' AGL) Kenai Belu a Unit 23-7 8. Property D~siqnation: 0. Field/Pool(s): ~` ~ A- 028142 Kenai Gas Field / Beluga & Tyonek Pools 11. Present Well Condition Summary: ~ Total Depth measured 9,320' feet Plugs (measured) N/A true vertical 7,965' feet Junk (measured) N/A Effective Depth measured g,23p' feet true vertical 7~87g~ feet Casing Length Size MD ND Burst Collapse Structural Conductor 100' 20" 121' 121' 3,060 psi 1,500 psi SurFace 1,374' 13-3/8" 1,395' 1,394' 3,450 psi 1,950 psi Intermediate 6,526' 9-5/8" 6,547' 5,297' 6,870 psi 4,750 psi Production 9,247' 3-1/2" 9,268' 7,913' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 6,678' - 9,193' True Vertical depth: 5,415' - 7,839' Excape Tubing 3-1/2" L-80 9,268' Tubing: (size, grade, and MD) Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): The approved perforation additions were not added because of the additional water infiltration issues that arose in some of the other Treatment descriptions including volumes used and final pressure: wells, in this program, after they were perforated. 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 Exploratory ^ Development ^~ Service ~ Daily Report of Well Operations 1. Well Status after work: Oil ^ 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: 308-351 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician ~ ~ Signature , Phone (907) 283-1371 Date October 8, 2009 Form 10-404 Revised 04/2006 ~j ~' ` ~ ' Submit Original Only ~uG~u',~ ~~~ ~~1~i~~]S~i6?~ ALASSA OIL A1~TD GAS CO1~T5ER~ATIOI~T COMAIISSIOl~ • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kyle Miranda Production Engineer Marathon Oil Company PO Box 1949 Kenai AK 996 1 1-1 949 ~, ~ 3 + Re: Kenai Gas Field, U. Tyonek/Beluga Gas Pool, Kenai Beluga Unit 23-7 Sundry Number: 308-351 Dear Mr. Miranda: 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 ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. 3 r ~ Chair DATED this _ day of October, 2008 Encl. M Marathon MARATHON Oil Company September 25, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application of Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 23-7 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Attached for your records is the10-403 Application of Sundry Approvals for KBU 23-7 well. Marathon requests permission to add 58' of perforations to the Beluga formation across the 6,647' - 7,712' interval. 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 Application of Sundry Approvals Current Well Schematic Work Procedure cc: Houston Well File Kenai Well File KJS KJ M STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ON APPLICATION FOR SUNDRY APPROVALS ~n aa~ ~~ ~Rn 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^~ Waive~'^ Ather^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change 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: Development ^ . Exploratory ^ 203-217' 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20532-00-00 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: , S ~ ^ Kenai Beluga Unit 23-7 pacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): f~'~ A- 028142 87' (21' AGL) ~ Kenai Gas Field /Beluga & Tyonek Pools 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): 9,320' ~ 7,965' _ 9,230'_ 7,876' - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 121' 121' 3,060 psi 1,500 psi Surface 1,374' 13-3/8" 7,395' 1,394' 3,450 psi 1,950 psi Intermediate 6,526' 9-5/8" 6,547' 5,297' 6,870 psi 4,750 psi Production 9,247' 3-1/2" 9,268' 7,913' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,678' - 9,193' 5,415' - 7,839' 3-1/2" L-80 9,268' 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 ^~ BOP Sketch ^ Exploratory ^ Development ^~ Service. ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 23, 2008 pil ^ 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 Kyl Miranda Title Production Engineer ~ / Signature ~ ~ Phone Date d ~ (907) 283-1370 September 25, 2008 ~° , ~~ ~; / ~ `~ COMMISSION USE ONLY /i N b ~ ~ ~ ~ 1 di i f l N if i i S d C C i un um er: on ons o approva : y omm ssion so that a representat ve may w tness ry t ot BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Plug Integrity ^ i Other: ~~-~~CC3C~~j ` ~~V°~(1Mfc.~~` ~v\GCCCJ~ ~ ~ ~ ~ ~~~-~~ s~ ~~ Subsequent Form Required:' (,.,~ (~ ~` APPROVED BY ~ 0 ~ ~ J THE COMMISSION D t / CO SS O a e: Approved by: MMI I NER _ ~k c~ ~ t ~ 2009 Form 10-403 Revised 06/2006 Submit in Duplicate ~~ ~,3p+os~ ®p ,~L O ~t~3 ~ t ~ ~ ~~ MARATHON Marathon Oil Corporation Field: Kenai Beluga Unit WBS: Not requested yet Pad: 14-6 KBU 23-7 September 18, 2008 Well Status: 1.525 MMcf/d @ 226 psi (SCADA 9-17-08) and 66 BWPD (TOW 9-17-08). Objective: Perforate the following Beluga sands. Depth and surface pressure to fire guns: 6647' - 6657' (10' net, 10' gun, single run) 7342' - 7362' (20' net, 20' gun, single run) 7684' - 7712' (28' net, 14' & 14' tandem, single run) Guns to be used: 2-3/8" RTG (Retrievable Tubing Gun) guns loaded 4 SPF 60 degree-phased with TAG-2375-402NTX charges and PX-1 firing head. API target performance: 0.27" entrance hole and 19.21" penetration. Max gun swell in air: 2.575" OD. Procedure• a) Remove well house. b) MI diesel man-lift. c) MIRU Expro E-line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment. d) Hold PJSM. e) PT lubricator to 2000 psi (MPSP+) with KCL H2O or methanol, weather dependent. f) RIH with 2.75" GR to minimum depth needed for CCL correlation. POOH GR. 2. a) RIH w/ 28' of guns (type shown above, 14' & 14' tandem guns, single run). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 1480 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 7684' - 7712' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. 3. a) RIH w/ 20' of guns (type shown above, 20' guns, single run). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 1410 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 7342' - 7362' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. 4. a) RIH w/ 10' of guns (type shown above, 10' guns, single run). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 1220 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 6647' - 6657' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. e) LD spent perf gun and lubricator. RD Expro. Return well to production. Flow test. 5. Produce well to sales. CONTACTS Ken Walsh: 907-283-1311 (w) Jennifer Enos: 713-296-3319 (w) 907-394-3060 (c) 713- 408-3583 (c) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (c) KGF Operators: 907-283-1305 Measured Depth TVD Tots Bottom Footage T~ Bottom 6647 6657 10 5387 5396 7342 7362 20 6030 6049 7684 7712 28 6353 6380 Formation Bottomhole pressure* Press 40% 60% DD DD 2316 926 1390 2712 1085 1627 2863 1145 1718 *No MFT data for formation pressures 40% DD Surface Pressure to fire guns (WAM calc) Gas .57 BHT 1223 109 1408 117 1475 120 KBU 23-7 Add perfs - MD Dammeyer 9/25/2008 5:32:36 PM 50-133-20532-00-00 A - 028142 is 87' (21' AGL) 60° 27' 36.75" N 151°15'54.42"W 2/17/2004 3/4/2004 3/9/2004 06:00 hrs TOC (est.) - ???' KBU 23-7 Pad 14-6 317' FSL, 1,105' FWL, Sec. 6, T4N, R11W, S.M. Excaae Svstem Details - BHP monitoring line volume tank located from 6,584' - 6,619' RKB - Ceramic flapper valves below each module as follows: Module 15 - 6,689' Module 14 - 6,757' Module 13 - 6,912' Module 12 - 6,951' Module 11 - 7,001' Module 10 - 7,109' Module 9 - 7,252' Module 8 - 7,318' Module 7 - 7,461' Module 6 - 7,563' Module 5 - 7,901' Module 4 - 8,156' Module 3 - 8,675' Module 2 - 8,750' Module 1 - NA .a 4' TD 9,320' MD 7,965' TVD PBTD 9,230' MD 7,876' TVD M MARATHON Conductor 20" K-55 133 ppf Top Bottom MD 0' 121' TVD 0' 121' 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,395' ND 0' 1,394' 16" hole Cmt w/ 398 sks (178 bbls) of 12.0 ppg, Type 1 cmt, 100% returns, 45 sks (20 bbls) to surface 9-5/8" L-80 40 ppf Mod BTC Top Bottom MD 0' 6,547' ND 0' 5,297' 12-1/4" hole Cmt w/ 842 sks (352 bbls) of 13.5 ppg, class G cmt, no cmt to surface 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 9,268' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,147 sks (319 bbls) of 15.8 ppg, class G cmt, 100% returns, no cmt to surface - 15 Excape modules placed - Red control line fires top 8 modules -Greer, control line fires middle 6 modules Well Name & Number: Kenai Beluga Unit 23-7 Lease: Kenai Gas Field, A-028142 County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 6,678' - 9,193' (TVD): 5,415' - 7,839' Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 3/10/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 9/25/2008 J~~ ,~1 . 4' r. i~ N - control line fires bottom 1 module - Ceramic flapper valves below each module Perfs MD (RKB): qr- ((,y,._ S Module 15 - 6,678'-6,688' Module 14 - 6,748'-6,758' Module 13 - 6,900'-6,910' Module 12 - 6,939'-6,949' ~ '~v' Module 11 - 6,990'-7,000' ~Y V v Module 10 - 7,098'-7,108' (J~ Module 9 - 7,243'-7,253' ~ Module 8 - 7,311'-7,321' ~'~3,y~_~'~ Module 7 - 7,451'-7,461' Module 6 - 7,553'-7,563' ' ' ,~~ ~ _ 1.,~~ ~ ~ Module 5 - 7,890 -7,900 Module 4- 8,144'-8,154' Module 3 - 8,661'-8,671' Module 2 - 8,738'-8,747' Module 1 - 9,183'-9,193' 1 ` ei s∎,.. . Casing & Cement Ill W ell Name: KENAI BELUGA UNIT 23 -7 Marathon wo - Z ti'f'›.Zt4 For String: Surface Casing Detail: Casing Description Prop Run? Run Date Set Depth (ftKB) Set Tension (10001bf) Wellbore Centralizers Scratchers Surface No 2/19/2004 00:00 1,395.0 0.0 KENAI BELUGA UNIT 23 -7 Comment Casing Components Jts Item Description Icon OD (n) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment I Csg Hd Upper Casing 13 5/8 13.625 4340 BTC 1.73 23.0 24.7 hanger Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment Csg Hd Lower Casing 13 5/8 12.375 4340 BTC 1.92 24.7 26.7 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 Partial Cut Jt Casing 13 3/8 12.375 • K -55 BTC 12.25 26.7 38.9 (black) Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 32 CASING JOINT(S) Casing 13 3/8 12.375 68.00 K -55 BTC 1,310.89 38.9 1,349.8 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 13 3/4 12.375 68.00 K -55 BTC 1.92 1,349.8 1,351.7 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 13 3/8 12.375 68.00 K -55 BTC 41.54 1,351.7 1,393.3 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 13 3/8 12.375 68.00 K -55 BTC 1.75 1,393.3 1,395.0 ThreadLock Y /N: Y SHOE shoe Cementing Job Details: - - . Cementing Start Date Cementing End Date Cementing Company 2/19/2004 00:00 ' 1 B.J. SERVICES Comment Coil tubing unit indicator: N Tool company: Check Ball Wait on cement (hrs): 12 Description Type String Wellbore SURFACE CASING ' Casi n g ' Surfa c e, 1,395.0ftKB KENAI BELUGA UNIT 23 -7 Cement Sta a #1 Description: . , . . . . . . ,- ..: . .. . , . ,_ .,.,-;. , .. - , Float Failed? 'Plug Failed? Full Retum? Pipe Reciprocated? 'Pipe Rotated? Pressure Held (psi) Yes Yes No No No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 1 0.0 1,396.0 Top Plug? Bottom Plug? Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Pump Start Time Pump End Time No ' No ( 6 ' Avg Pump Rate (bbl /min) 6' Drill Out Dia (in) 'Final Pump Pressure (psi) O O TPlug Bump Pressure (psi) !Pressure Release Date Comment II Annular flow after cement job (Y /N): N Hours circulated between stages: 3 ii JUN 1 $ ZWZ Pressure before cementing: 400 D Excess volume measured from: Gauge Hole Returns: 11.8 ppg Time cementing mixing started: 09:16 Cement Fluids LEAD Class ' Density (lb/gal) Yield (ft /sack) Volume Pumped (bbl) CLASS G 12.00' .4. .. .. . 2.5.11 179.0 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 12 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 107 Fluid Type Amount (sacks) Mix H2O Ratio (gal/sack) Percent Excess Pumped (%) LEAD 400 11.281 50.0 Cement Fluid Additives . Add , Amount . Amount Units - , " Cone Unit . . - Conn . • • . Type - , CD32 0.0 FP6L 0.0 LW6 0.0 MPA -1 0.0 www.peloton.com Page 1/2 Report Printed: 8/4/2011 • JJ • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 For String: Surface Cement Fluid Additives Add Amount Amount Units Conc Unit Conc Type Mud Clean 0.0 R3 0.0 Sod Metasc 0.0 Wellheads Install Date Type Job Removed Date 'Comment www.peloton.com Page 2/2 Report Printed: 8/4/2011 Casing & Cement • Marathon oil Well Name: KENAI BELUGA UNIT 23 -7 For String: Intermediate Casing Detail: Casing Description Prop Run? Run Date Set Depth (ftKB) Set Tension (1000lbf) Wellbore Centralizers Scratchers Intermediate No 2/29/2004 00:00 6,546.7 0.0 KENAI BELUGA UNIT 23 -7 Comment Casing Components Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING HANGER Casing 9 5/8 8.835 L -80 Acme 1.37 23.0 24.4 hanger Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 PUP JOINT Casing 9 5/8 8.835 40.00 L -80 BTC 3.11 24.4 27.5 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 15 CASING JOINT(S) Casing 9 5/8 8.835 40.00 L -80 BTC 6,432.75 27.5 6,460.2 ThreadLock Y /N: Y 2 (black) Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 9 5/8 8.835 L -80 BTC 1.50 6,460.2 6,461.7 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CASING JOINT(S) Casing 9 5/8 8.835 40.00 L -80 BTC 83.30 6,461.7 6,545.0 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 9 5/8 8.835 L -80 BTC 1.71 6,545.0 6,546.7 ThreadLock Y /N: Y SHOE shoe Cementing Job_Details Cementing Start Date Cementing End Date Cementing Company 2/29/2004 00:00 B.J. SERVICES Comment Coil tubing unit indicator: N Tool company: Ball Check Wait on cement (hrs): 24 Description Type String Wellbore INTERMEDIATE CASING ' Casing I Intermediate, 6,546.7ftKB KENAI BELUGA UNIT 23 -7 Cement Stage #1 Description: • Float Failed? !Plug Failed? Full Retum? "Pipe Reciprocated? 'Pipe Rotated? Pressure Held (psi) Yes Yes Yes Yes No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 1 3,202.0 6,547.0 Top Plug? NO !Bottom Plug? No !Initial Pump Rate (bbl/min) 6 'Final Pump Rate (bbl /min) Pump Start Time Pump End Time Avg Pump Rate (bbl /min) Out Dia (in) Final Pump Pressure (psi) DnII Plug Bump Pressure (psi) Pressure Release Date 5' 0.0' Comment PIPE MOVEMENT NOTES: Drag down 125000 Drag up 225000 Pipe movement: RECIPROCATING Time stopped reciprocating: 21:00 Time started reciprocating: 14:00 Annular flow after cement job (Y /N): N Hours circulated between stages: 6 Pressure before cementing: 500 Returns: 23 to 100% Time cementing mixing started: 21:16 Cement Fluids LEAD Class Yield (fN /sack) Volume Pumped (bbl) CLASS G 'Density (Ib /gal) 13.50' 1.841 276.0 Comment Time displacement started: : Wait on Cement Time: 24 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 186.4 Fluid Type ' Amount (sacks) Mix H2O Ratio (gal /sack) Percent Excess Pumped ( %) LEAD 844 9.28 Cement Fluid Additives Add - -- Amount ' - - . Amount Units - 'Cone Unit • . . ' . - Conc '. - - ' Type . - - ' ASA-301 0.1 % BWOC BA -56 2.5 % BWOC www.peloton.com Page 1/2 Report Printed: 8/4/2011 IAN I/ • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 For String: Intermediate Cement Fluid Additives Add - Amount Amount Units - Conc Unit - Conc Type BA -90 10.0 % BWOC CaChlor 2.0 % BWOC FP -6L 1.0 GAL SMS 0.5 % BWOC Wellheads Install Date (Type Job Removed Date 'Comment www.peloton.com Page 2/2 Report Printed: 8/4/2011 ling • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 For String: Production Casing Detail: Casing Description Prop Run? Run Date Set Depth (ftKB) Set Tension (10001bf) Wellbore Centralizers Scratchers Production No 3/9/2004 00:00 9,273.8 0.0 KENAI BELUGA UNIT 23 -7 Comment Casing Components Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 PARTIAL JOINT Casing 3 1/2 2.992 L -80 EUE 62.81 -26.9 35.9 (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 20 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 6,553.90 35.9 6,589.8 9 (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 EUE 35.10 6,589.8 6,624.9 PRESSURE Module MODULE Jts Item Descnption Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 5.90 6,624.9 6,630.8 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 31.37 6,630.8 6,662.1 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.79 6,662.1 6,700.9 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 29.73 6,700.9 6,730.7 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.77 6,730.7 6,769.4 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 22.07 6,769.4 6,791.5 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 94.15 6,791.5 6,885.6 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 77.48 6,885.6 6,963.1 MODULES Module Jts Item Description ' Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 11.82 6,963.1 6,974.9 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.73 6,974.9 7,013.7 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 5.93 7,013.7 7,019.6 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 62.93 7,019.6 7,082.5 (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 3 1/2 2.992 9.30 L -80 EUE 38.70 7,082.5 7,121.2 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 9.97 7,121.2 7,131.2 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 94.10 7,131.2 7,225.3 (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.73 7,225.3 7,264.0 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 27.91 7,264.0 7,291.9 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.63 7,291.9 7,330.6 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 9.98 7,330.6 7,340.6 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 94.28 7,340.6 7,434.8 (black) www.peloton.com Page 1/3 Report Printed: 8/4/2011 fiAN, 0 Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 L•+ For String: Production Casing Components Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.70 7,434.8 7,473.5 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 62.73 7,473.5 7,536.3 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.73 7,536.3 7,575.0 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 17.62 7,575.0 7,592.6 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 9 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 282.32 7,592.6 7,874.9 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.72 7,874.9 7,913.7 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 27.65 7,913.7 7,941.3 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 6 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 188.11 7,941.3 8,129.4 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.81 8,129.4 8,168.2 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 9.97 8,168.2 8,178.2 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 15 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 470.61 8,178.2 8,648.8 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.74 8,648.8 8,687.5 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 9.30 L -80 EUE 4.92 8,687.5 8,692.5 ASSEMBLY (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 31.44 8,692.5 8,723.9 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 38.77 8,723.9 8,762.7 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 13 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 EUE 408.06 8,762.7 9,170.7 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Excape 31/2 2.992 9.30 L -80 EUE 35.05 9,170.7 9,205.8 MODULES Module Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 L -80 EUE 31.43 9,205.8 9,237.2 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 3 1/2 2.992 EUE 0.60 9,237.2 9,237.8 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 L -80 EUE 31.43 9,237.8 9,269.2 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 PUP JOINT Casing 3 1/2 2.992 L -80 EUE 4.07 9,269.2 9,273.3 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 3 1/2 2.992 EUE 0.49 9,273.3 9,273.8 ThreadLock Y /N: Y SHOE shoe Cementing. Job. Details: Cementing Start Date Cementing End Date Cementing Company 3/9/2004 00:00 ( B.J. SERVICES Comment Coil tubing unit indicator: N Tool company: Ball check Wait on cement (hrs): 8 Description Type String Wellbore PRODUCTION CASING Casing Production, 9,273.8ftKB KENAI BELUGA UNIT 23 -7 www.peloton.com Page 2/3 Report Printed: 8/4/2011 {/j Casing & Cement • Marathon oil Well Name: KENAI BELUGA UNIT 23 -7 For String: Production Cement Stage #1 Description: Float Failed" Plug Failed' Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) Yes Yes No Yes No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 1 6,138.0 9,320.0 Top Plug? Bottom Plug? Initial Pump Rate (bbl /min) Final Pump Rate (bbl /min) 'Pump Start Time Pump End Time No No 7 Avg Pump Rate (bbl /min) Drill Out Dia (in) Final Pump Pressure (psi) Plug Bump Pressure (psi) Pressure Release Date 6 0.0 Comment PIPE MOVEMENT NOTES: Drag down 70000 Drag up 125000 Pipe movement: RECIPROCATING Time stopped reciprocating: 16:40 Time started reciprocating: 01:00 Annular flow after cement job (Y /N): N Hours circulated between stages: 6 Pressure before cementing: 800 Excess volume measured from: Caliper Log Returns: 0 Time cementing mixing started: 02:52 Cement Fluids SPACER Class I Density (lb/gal) Yield (ft' /sack) Volume Pumped (bbl) CLASS G 18.80 1.17 244.0 Comment Displacement fluid used: BRINE Time displacement started: : Wait on Cement Time: 8 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 139 Fluid Type ' Amount (sacks) Mix H2O Ratio (gal /sack) Percent Excess Pumped (%) SPACER 1,175 4.961 30.0 Cement Fluid Additives Add - 'Amount . . - Amount Units Conc Unit ' - Conc - - ' - - Type - BA -56 1.2 % BWOC FP-6L 1.0 GPHS KCL 3.0 % BWOC R3 0.2 % BWOC Wellheads . Install Date Type 'Job 'Removed Date 'Comment I I www.peloton.com Page 3/3 Report Printed: 8/4/2011 erations Summary Report by J• p rY p Y Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 703•Zt+— Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011 W01 KENAI I 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 20.12 26.52 6.40 2/17/2004 Daily Operations Report Date: 4/12/2004 Job Category: COMPLETION 24 Hr Summary RIH with 2.5 "" OD GR. Run Expro Bond. Ops Trouble Start Time . End Time Our (hr) Ops Code Activity Code Status Code Com 14:40 15:00 0.33 RURD ELEC AF Meet Expro at KGF Office. Obtain Work Permit. Travel to KBU 23 -7 location. 15:00 15:30 0.50 RURD ELEC AF Spot and RU equipment. PU 2.5 "" OD GR. Prepare to RIH to tag PBTD. 15:30 17:40 2.17 WAITON EQIP TA LOWE Wait on Vacuum Truck to arrive location. 17:40 18:00 0.33 TAG BOTM AF RIH with 2.5 GR. Tagged PBTD @ 9231'. POOH and LD GR. 18:00 19:45 1.75 LOG CSG AF PU Expro Dual Reciever Sonic Signature Radial Bond Log Tool. RIH to PBTD © 9231'. 19:45 22:20 2.58 LOG CSG AF Log with CBL from PBTD to 5700' (300' above TOC @ 6020'). 22:20 00:00 1.67 RURD ELEC AF POOH with CBL. LD CBL tool and RD Expro. 00:00 01:30 1.50 LOG CSG AF Finalize log presentations and paperwork. Report Date: 7/15/2004 Job Category: COMPLETION 24 Hr Summary Start spotting water tanks for frac job. Start hauling water. Ops - . Trouble . . • Start time 3 End Time Dtir4hr) : - Ops Code Activity Code Status . Code . Com 06:00 23:00 17.00 RURD STIM AF Spot water tanks and spill guards. Start hauling water. Report Date: 7/16/2004 Job Category: COMPLETION 24 Hr Summary Haul water to location and offload into frac tanks. Qp . , - trouble.' , Start Time . End Time . .our Qv) ,, -' Ops Code Activity Code - Status -` Code - - - Com - 06 :00 23:00 17.00 RURD STIM AF Haul water to location and offload into frac tanks Report Date: 7/17/2004 Job Category: COMPLETION 24 Hr Summary Haul water to location and offload into frac tanks. Ops ' Trouble, Starttaae Time . Dur-{tir) , Ops Code Activity Code - - -- Status- Code Com 06:00 14:00 8.00 RURD STIM AF Haul water to location and transfer to frac tanks. Report Date: 7/18/2004 Job Category: COMPLETION 24 Hr Summary Finish hauling water to location. Start heating water and rigging up additional frac equipment and wellhead scaffolding. - Ops- .- -- firouble •'StartTStae Dtw(tu .,003 Code r Activity code - Status Gode Corti . • 06:00 20:00 14.00 RURD STIM AF Finish hauling water to frac tanks. Manifold up tanks and start heating water for frac job. RU scaffolding around wellhead. Report Date: 7/19/2004 Job Category: COMPLETION 24 Hr Summary Haul frac equiment to location and start rigging up same. Continue heating up frac water. Start End Time Our (hr) :Ops Coda . ' Activity Cede . ,- Status Code , Com . 06:00 22:30 16.50 RURD STIM AF Haul test equipment to location. Continue rigging up location for frac job and heating water. Report Date: 7/20/2004 Job Category: COMPLETION 24 Hr Summary Laid down spill guard material and start berming frac equipment and lines. Continued to rig up flowback test equipment, frac trucks and lines. Ops' Troutate - Start Time End Time Our (hr) Ops Code Activity Code ,.; . Status - ; .Code Com 06:00 18:00 12.00 RURD STIM AF Lay down spill guard material and start berming all frac equipment and lines. Continue rigging up flowback test and frac equipment. Report Date: 7/21/2004 Job Category: COMPLETION 24 Hr Summary Completed location rig up. Pressure tested frac lines to 8500 psi and coil tubing and flowback equipment to 4500 psi. Perforated module one and pumped into well to verify guns fired. Ops double , Start - End - EndT1gte .Dui(tw) Ops Code _ Activity Code. - Status Code Cort(•. 06:00 10:00 4.00 RURD STIM AF Continue to rig up flowback test equipment and frac turcks and lines. www.peloton.com Page 1/5 Report Printed: 8/2/2011 MP *Operations Summary Report by .� Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 • Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011 W01 KENAI ALASKA USA Casing Flange Elevation (m) (Ground Elevation (m) KB- Casing Flange Distance (m) IKB- Ground Distance (m) Spud Date Rig Release Date 0.00 20.12 26.52 6.40 2/17/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status- Code Com 10:00 13:00 3.00 PERF CSG AF RU expro lines and monitoring van and equipment. Pressure up on yellow control line to perforate module one perfs at 9183 -9193' MD. Pressured up to 5000 psi without indication of guns firing. Bled pressure off and repressured to 4500 psi. Still no definite indication fo guns firing. RU BJ lines and pressure test to 5000 psi. Pump into well to determine if module one guns fired. Pumped in at 3 -5 bpm with 4500 psi verifying perf guns fired. RD BJ and Expro 13:00 18:00 5.00 TEST EQIP AF Completed rigging up all frac, coil, and flowback equipment. Tested all frac trucks and lines to 8500 psi. Tested coil tubing and flowbackk lines and equipment to 4500 psi. Report Date: 7/22/2004 Job Category: COMPLETION 24 Hr Summary Frac 14 of 15 excape modules. Module 1 tight. Cleaned out all flappers and jetted well in with Coiled Tubing. Commenced well testing operations. Ops Trouble - Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 07:00 1.00 SAFETY MTG AF Hold prejob safety meeting discussing frac operations. Warm up pump trucks and prime all chem pumps. 07:00 08:00 1.00 PUMP FRAC AF Prepare for and perform injection test into mod 1 perfs. Max pressure = 6800 psi. Two step shut down. ISIP = 4232. F.G.= 0.98 psi /ft. Calculated 6 perfs open. 08:00 08:30 0.50 PUMP FRAC AF Pump 10 bbl scour pad of .5 -1 ppg. Had no effect. Inject 45 bbl at 22 BPM and 6500 psi. Reduce rate to 15 bpm at 5500 psi. No more perfs appeared to open. Decision made not to frac mod 1. Total load = 338 bbls. All volumes tagged with Protechnics CFT 1000 tracer and SC -46 RA marker. 08:30 09:00 0.50 PUMP FRAC AF Pert mod 2 perfs (8737 - 8747' MD). Frac w/ BJ Lightning_V wtr based system at 15 BPM at max TP = 5000 psi. Ramp 2.0 - 6.0 ppa. Place 26000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 244 bbl. Tagged w/ ProTechnics CFT 1100 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 09:00 09:45 0.75 PUMP FRAC AF Pert mod 3 perfs (8661' - 8671' MD). Frac w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 4950 psi. Ramp 2.0 - 6.0 ppa. Place 26000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 247 bbl. Tagged w/ ProTechnics CFT 1200 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. (Changed fluid to 16 pound gel system in 6 ppg stage) 09:45 10:15 0.50 PUMP FRAC AF Perf mod 4 perfs (8144' - 8154' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 5700 psi. Ramp 2.0 - 6.0 ppa. Place 36200 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 285 bbl. Tagged w/ ProTechnics CFT 1400 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 10:15 10:45 0.50 PUMP FRAC AF Perf mod 5 perfs (7890' - 7900' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4100 psi. Ramp 2.0 - 6.0 ppa. Place 36000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 282 bbl. Tagged w/ ProTechnics CFT 1500 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 10:45 11:30 0.75 PUMP FRAC AF Perf mod 6 perfs (7553' - 7563' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3950 psi. Ramp 2.0 - 6.0 ppa. Place 23000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 216 bbl. Tagged w/ ProTechnics CFT 1600 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 11:30 12:15 0.75' PUMP FRAC AF Pert mod 7 perfs (7451' - 7461' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 6.0 ppa. Place 32000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 255 bbl. Tagged w/ ProTechnics CFT 1700 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 12:15 12:45 0.50 PUMP FRAC AF Perf mod 8 perfs (7311' - 7321' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP =3200 psi. Ramp 2.0 - 6.0 ppa. Place 26400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 226 bbl. Tagged w/ ProTechnics CFT 1900 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. www.peloton.com Page 2/5 Report Printed: 8/2/2011 fic4$11 •Operations Summary Report by • Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State/Province Country 6006004N011 W01 KENAI 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 20.12 26.52 6.40 2/17/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 12:45 13:15 0.50 PUMP FRAC AF Perf mod 9 perfs (7243' - 7253' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3000 psi. Ramp 2.0 - 6.0 ppa. Place 26400 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 223 bbl. Tagged w/ ProTechnics CFT 2000 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 13:15 13:45 0.50 PUMP FRAC AF Pert mod 10 perfs (7098' - 7108' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3300 psi. Ramp 2.0 - 6.0 ppa. Place 24600 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 219 bbl. Tagged w/ ProTechnics CFT 2100 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 13:45 14:15 0.50 PUMP FRAC AF Pert mod 11 perfs (6990' - 7000' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3500 psi. Ramp 2.0 - 6.0 ppa. Place 24000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 217 bbl. Tagged w/ ProTechnics CFT 2200 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 14:15 15:00 0.75 PUMP FRAC AF Pert mod 12 perfs (6939' - 6949' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3200 psi. Ramp 2.0 - 6.0 ppa. Place 21000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 202 bbl. Tagged w/ ProTechnics CFT 2200 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 15:00 15:15 0.25 PUMP FRAC AF Perf mod 13 perfs (6900' - 6910' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 2950 psi. Ramp 2.0 - 6.0 ppa. Place 25200 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 214 bbl. Tagged w/ ProTechnics CFT 2200 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 15:15 15:45 0.50 PUMP FRAC AF Pert mod 14 perfs (6748' - 6758' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 2800 psi. Ramp 2.0 - 6.0 ppa. Place 23600 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 204 bbl. Tagged w/ ProTechnics CFT 2400 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 15:45 16:00 0.25 PUMP FRAC AF Perf mod 15 perfs (6678' - 6688' MD). Frac w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4200 psi. Ramp 2.0 - 6.0 ppa. Place 28600 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 230 bbl. Tagged w/ ProTechnics CFT 2500 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 16:00 18:30 2.50 RURD STIM AF Finish frac operations and RD and clean up frac chemicals, trucks, etc. RU coil tubing equipment for well cleanout. Total frac load = 3602 Bbls. RU coil tubing equipment. 18:30 20:30 2.00 TRIP BHA AF Run in Hole with Coiled Tubing. Broke flappers for modules 15, 14, 13, 12, and 11. Lost returns upon breaking flapper for Module 11 at 6990. Regained partial returns only. 20:30 22:30 2.00 PUMP N2 AF Prepare Nitrogen unit and pump. RIH with minimum N2 rate with 3/4 to full returns. Break flappers for Modules 10 through 2. Broke all module flappers from Module 15 through 2 at RKB of 6676, 6746, 6900, 6939, 6990, 7097, 7240, 7306, 7449, 7551, 7890, 8144, 8661, and 8737, respectively. 22:30 23:00 0.50 TRIP BHA AF Run in Hole with Coiled Tubing to PBTS of 9215' RKB. CBU. 23:00 05:00 6.00 PUMP N2 AF Pooh to 6500' and jet well in with N2 at 750 scfm. Well unstable and flwoing no gas, all broken frac load water. Montior well for flow. No flow. Continue jetting with N2. Monitor well for flow. Well flowing very sporadically. RIH jetting with N2 across all perforations to 9200'. POOH jetting well in with 750 scfm until all N2 was used. Finish POOH. Well/ flowing with 410 npsi FTP. RD coil tubing injector head and secure CT equipmjent. 05:00 06:00 1.00 FLOW BACK AF Monitor well flow through choke manifold and gas buster. Throughout all clean out and flow periods well produced small amount of proppant slugs. Well unloading broken frac fluid with FTP = 350 -400 psi. Total frac load recovery = 397 bbls or 11% of 3602 bbls total load. Report Date: 7/23/2004 Job Category: COMPLETION 24 Hr Summary Flow test well. Well flowing at 2.6 MMCFD, 648 BWPD, with a FTP of 640 psig on a 46/64 choke. www.peloton.com Page 3/5 Report Printed: 8/2/2011 ' \. )j/ "'Operations Summary Report by Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country 6006004N011 W01 KENAI 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 20.12 26.521 6.40 2/17/2004 Ops Trouble Start Time End Time Dur (hr) - Ops Code Activity Code Status Code Com 06:00 06:00 24.00 FLOW TEST AF Flow Well to test. Well gradually cleaning up. Put well to low pressures sales at 1430 hours on 7/22/04. Well now making 2.6 MMCFD, 648 BWPD with a FTP of 640 psig on a 46/64th choke. Report Date: 7/24/2004 Job Category: COMPLETION 24 Hr Summary Unload and flow test well. Well making 3.1 MMCFD, 476 BWPD on a 50/64 th choke with a 640 psig FTP. Ops- Trouble - Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 06:00 24.00 FLOW TEST AF Flow Well for clean up and testing. Increase choke to 50/64th. Well now making 3.1 MMCFD with a 640 psig FTP. Well still unloading approximately 500 BWPD. Report Date: 7/25/2004 Job Category: COMPLETION 24 Hr Summary Flow well to test equipment. Well making 3.8 MMCFD, 346 BWPD on a 50/64th choke with a FTP of 630 psig. Ops Trouble Start Time End Time _ Dur (hr) Ops Code- - Activity Code Status - Code - Com 06:00 06:00 24.00 FLOW TEST AF Flow well to test equipment. As of 0530 7/25/04, Well making 3.8MMCFD, 346 BWPD with a FTP of 630 psig ona 50 /64th choke. Total fluid recovery of 2215 bbls = 61.5% of 3602 frac job load. Report Date: 7/26/2004 Job Category: COMPLETION 24 Hr Summary Cleaned up well to LP production system. LP system developed leak. Switched well to HP production system and continued to clean up and flow test. Ops Trouble - • Start Tone Epd Time - Our ( Ops-Code Activity Code - - Status . Code Com 06 :00 08:45 2.75 FLOW TEST AF Flow well to LP production system. Production opoerators indicated they developed leak in LP system. Prepare to switch well to HP production system. 08:45 06:00 21.25 FLOW TEST AF Flow well to HP production system and continue to clean up and flow test. As of 0530 7/26/04 well making 3.2 MMCFD, and 203 BWPD on an open choke with a 880 psig FTP. Well riding line pressure. Total fluid recovered = 2481 or +/- 69% of total frac load of 3602 bbls. Report Date: 7/27/2004 Job Category: COMPLETION 24 Hr Summary Continued flowing well to HP production system. At 0600 7/27/04 well making 3.168 MMCFD, 341 BWD on an open choke with a FTP of 860 psig. Ops Trouble Start Txriee.. End Time "` -- .Dur {tu) ' _ Ops Code " .. Activity Code _,_; Status . • r Code , - Com 06:00 06:00 24.00 FLOW TEST AF Flow well to HP production system. At 0600 7/27/04 well producing 3.168 MMCFD, 341 BWPD, on an opoen choke with a FTP = 860 psig. Well making just a trace of gray formation fines. Total fluid produced = 2746 bbls or 76.2% of total frac load of 3602 bbls. Report Date: 11/6/2004 Job Category: COMPLETION 24 Hr Summary No operational information, except - waiting on equipment. t. Ops Trouble Start Time End.Time Die Mr) . Ops Code . Activity Code Status. .Code Com , 08:00 08:30 0.50 SAFETY MTG 08:30 10:00 1.50 WAITON EQIP Report Date: 11/7/2004 Job Category: COMPLETION 24 Hr Summary RU in attempt to run Protechnics MPLT. RIH w/ 2"" gauge cutter and tag high at 6915'. RIH and attempt to work with 1 -3/4 "" bailer without making any progress. Grabbed a sample of frac sand and small coal pieces. Qps Trouble • (ht) Ops Code Activity Code Status Start Time El Time - : Dur .. Code ' 08:00 08:15 0.25 SAFETY MTG Arrive at office. Sign in. Hold safety meeting. Obtain permit. 08:15 10:55 2.67 RURD SLIK RU wireline equipment 10:55 11:00 0.08 TEST BOPE Pressure test lubricator to WHP. 11:00 12:00 1.00 RUNPUL SLIK TA NDJK RIH w/ 2 "" gauge cutter. Tag up at 6915' KB. Unable to pass. POOH. 12:00 12:20 0.33 PULD BHA TA NDJK PU 1 -3/4 "" DD bailer. 12:20 14:00 1.67 RUNPUL SLIK TA NDJK RIH w/ 1 -3/4 "" bailer to 6915' without making any progress. P001-1. Bailer is full of frac sand. 14:00 15:00 1.00 RURD SLIK RD slickline Report Date: 11/8/2004 Job Category: COMPLETION 24 Hr Summary Ran 1.75 "" DD bailer. Tagged in 5 modules and tagged TD at 8720. Recovered full bailer of frac sand. Ran 2 "" GC to 8726' WLMD. Ran Protechnics Spectral GR from 6300 - 8720. Good data recovery. www.peloton.com Page 4/5 Report Printed: 8/2/2011 ,/jVII .� Operations Summary Report by Marathon Oil Well Name: KENAI BELUGA UNIT 23 -7 Qtr/Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011 W01 KENAI 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 20.12 26.52 6.40 2/17/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 10:00 2.00 RURD SLIK AF RU Pollard Wireline. Well dropped to 1MM and unloaded during the night at 7MM. Currently producting 2.8MM. 10:00 10:35 0.58 BAIL FILL AF Ran 1.75 "" DD bailer to 8720' WLMD. Tagged and worked through 6945, • 7105, 7249, 7450, 8659. Well producing 2.8 MM. 10:35 11:35 1.00 RUNPUL SLIK AF POH. Bailer fulol of frac sand. 11:35 12:40 1.08 RUNPUL SLIK AF PU 2 "" beveled GC and drift well. Tag at 8726' WLMD. 12:40 13:33 0.88 RURD SLIK AF LD GC and PU Protechnics spetral GR tool. 13:33 14:10 0.62 RUNPUL SLIK AF RIH Spectral GR 14:10 16:49 2.65 LOG CSG AF Log 6300 - 8720 down and up at 30' /min. 16:49 17:20 0.52 RUNPUL SLIK AF POH. 17:20 18:10 0.83 SECURE WELL AF RD for night. Report Date: 11/9/2004 Job Category: COMPLETION 24 Hr Summary Ran Petrotech memory PLT. Logged 6600' - 8700' up and down passes at 30', 60', and 90' /min. Tagged 4 places runningn in and hung in 1 coming out. Ops ' - Trouble - . Start,Tare „ .End Time Dur {hr),. Ops Code . Activity Code . .Status, ; ,Code . Com 08:30 09:54 1.40 RURD ELEC AF RU Pollard wireline and PU Protechnics memory PLT tool string 09:54 10:26 0.53 RUNPUL ELEC AF RIH PLT. 10:26 14:52 4.43 LOG CSG AF Log 30, 60 andf 90' /min up and down passes form 6600' - 8700'. Tagged at 7900', 8315', 8345', and 8530' on 30' /min down pass. Hung up at 7530' on 30' /min up pass. Faster passes were without incident. 14:52 15:30 0.63 RUNPUL ELEC AF POH. 15:30 16:30 1.00 RURD ELEC AF RDMO. Report Date: 12/30/2004 Job Category: COMPLETION 24 Hr Summary MI RU wire line RIH tagged fill. Worked bailer. POOH with bailer full of sand. Ops ' _Trouble. • Start Time „ End Time Dur {hr) , - Ops Code ,-, Activity Code Status, . _ Code - Com. . 08:00 09:15 1.25 RURD SLIK MIRU wire line unit, held a PJSM and discussed procedure with crew. MU 2.0 "" DD bailer. 09:15 10:30 1.25 TEST ' BOPE PT lubricator with well head pressure. WHP= 820 psig. No leaks. RIH 10:30 11:30 1.00 BAIL FILL RIH tag fill at 8725' KBD worked bailer. POOH 11:30 12:00 0.50 BAIL ' FILL OOH with bailer, bailer full of sand. 12:00 12:30 0.50 RURD SLIK RD unit move to 33 -1. Note:Bottom two modules covered over with sand. www.peloton.com Page 5/5 Report Printed: 8/2/2011 1 • • -' ~r '• ~ 03/01/2008 DO NOT PLACE ~'. ~. ~,~. ~R "' , _. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc ~ ~ 'A--.....~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2032170 Well Name/No. KENAI BELUGA UNIT 23-7 Operator MARATHON OIL CO Sp &.4.. J. /7 Ft..b)..6 ~y API No. 50-133-20532-00-00 MD 9320..... TVD 7965 r Completion Date 7/23/2004/ Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ---- DATA INFORMATION Types Electric or Other Logs Run: SP/GR-IEL-Density/Neutron-Sonic-Single Arm Caliper Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH 1 Start Stop CH Received Comments . Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? V ~ Chips Received? ~ Analysis ~ Received? Daily History Received? ~/N vI@:) Formation Tops Comments: ~~ . ~omPliance Reviewed By: --Þ Date: ~"") ~ ~Cø . . Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-296-3397 August 22, 2006 Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7th Avenue, Suite 100 Pu1chorage,AJC 99501 HAND DELIVERED RE: Marathon Oil Company KBU 23-7 CONFIDENTIAL Dear Mr. Okland: Confidential digital data for the above referenced well is enclosed. The CD contents are listed below: LAS File ~ \u(Dvf! ~KBU 23·7 MAIN 2.las ~ KBU 23-7 REPEAT 2,las ~kbu_23-7 _dir.las ~ kbu_23-7 Jf1udlog.las ~ kbu_23-7 JepeaUld.las Precision Data Package tJ'Marathon_KBU_23-7 jld.dpk To confirm receipt of this data, please sign and fax a copy of this transmittal to me at 713-499-8504. Thank you, ~ Kaynell Zeman Engineering Technician Enclosure RECEIVED' AtJG2 2 ZOOf) A1Iski Oil & GIS Cons. COlT1llúliaa A"Ghar,ue . te -. . p..ecelVe¿.¡r---f\ Date: ~~) Lid ).03 - ~l ") e - Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Marathon Oil Company August 27, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Revised Completion Report 10-407 for permit 203-217 Field: Kenai Gas Field / Beluga & Tyonek Well: KBU 23-7 Dear Mr. Aubert, Enclosed please find an updated Well Completion Report for Kenai Gas Field well KBU 23-7 and associated well operations summary. As previously communicated, this well has been completed cased hole with a 3.5" Excape monobore production string to surface. The well was fracture stimulated on July 21, 2004. This revised 10-407 is being submitted to include final completion and production test information. Should you require further information, I can be reached at 907-529-0524 / 713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, C'~D~ Sr. Completions Engineer Enclosures: Completion Report Operations Summary RECEIVED AUG 3 02004 Alaska Oil & Gas Cons. Commission Anchorage f e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilO Gas~ p~gedOAbandoned 0 Suspended 0 WAGO 1b. Well Class: 20MC 25.105 2OMC25.110 Development Exploratory ~ GINJ 0 W1NJO WDSPLO No. of Completions 1 Other Service Stratigraphic Test 0 2. Operator: 5. Date Comp., Susp., '7 ¡2~~ Permit to Drill Number: Name: Marathon Oil Company or Aband: ~ ~ 203-217 3 Address: 6. Date Spudded: API Number: P.O. Box 196168, Anchorage, AI< 99519-6168 2/1712004 50- 133-20532-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number 3/4/2004 Kenai Beluga Unit 23-7 Surface: 317' FSL, 1105' FWL, Sec. 6, T4N, R11W, S.M. 8. KB Elevation (ft.): 15. FieIdlPool(s): 87 Top of Productive 2704.92' FNL, 1977.74' FWL, Sec. 7, T4N, R11W, S.M. 9. Plug Back Depth (MD + Beluga & Tyonek Horizon: TVD): 9230' MD /7876' TVD Total Depth: 3306.8' FNL, 2145.86' FWL, Sec. 7, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD): 16. Property Designation: 9320' MD /7965' TVD A-028142 Surface: x- 272,019.199 y- 2,362,371.636 Zone- 4 11. Depth where SSSV Set: 17. Land Use Permit: NA TPI x- 272,833.530 y- 2,359,333.590 Zone- 4 NA feetMD 19. Water Depth, if Offshore: 20. Thickness of Permafrost: Total DeDth x- 272,990.020 y- 2,358,728.610 Zone- 4 NA feet MSL NA 18. Directional Survey: Yes~ NOD 21. Logs Run: SP/GR-IEL-DensitylNeutron-Sonic-Single Arm Caliper 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETIING DEPTH MD SETIING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20' 133.0 K-55 0 121 0 121 Driven NA NA 13-3/8' 68.0 K-55 0 1395 0 1394 16' 398 sx NA 9-5/8' 47.0 L-80 0 6547 0 5297 12-1/4' 842 sx NA 3-1/2' 9.3 L-80 0 9268 0 7344 8-1/2' 1147 sx 100,000 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: 6678-6688', 6748-6758', 6900-6910', 6939-6949', 6990-7000', 7098-7108', 3-112' 9268 NA 7243-7253',7311-7321',7451-7461',7553-7563', 7890-7900', 8144-8154', 8661-8671',8738-8747',9183-9193' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED TVD: 5415-5424', 5479-5468', 5618-5628', 5655-5664', 5702-5711', 5802-5811', See No. 23 5938-5947',8001-8010',6133-6142',6229-6238',6551-6561',6799-6809', 7311-7320',7386-7396',7829-7839' 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: GaS-Oil Ratio: 7/25/2004 24 Test Period -~ NA 3,800 346 50164 NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Water-Bbl: oil Gravity - API (corr): Press: 630 0 24-Hour Ratl-~ NA 3,800 346 NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if nessary). RECEIVED Submit core chips; if none, state ·none·. .- None AUG 3 0 '2.004 ,. :v~î~; ¡LiN //? lJ~s ORtG\NAL Alaska Oil & Gas Cans. Coma ~ . . V Villi I~' IIVY-n;:II'O ~ 4/2003 ssion CONTINUED ON REVERSE SIDE ,/ (9Y RfI)MS BFl SEP 0 1 1~n~ e e 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None"· None None KECEIVED AUG 3 02004 Alaska Oil & Gas Cons. Commissio Anchorage 30. Ust of Attachments: Directional Survey, operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of OT>/ knowledge. Contact Printed Name James R. Thomsoon Title Sr. completions Engineer Signature ~ -7i~ 'SÀ Phone 907.529_0524/713.296·2730 Date 8/27/2004 ! 1 -, V G.".""" ThI. to<m. _10.._ . -""" ",,' """'".... oon<iO""'''''''' """ .. 00" - ~ - """..... " _loa. ........... """",,,..,,,,,, _ """ ",.'1" we' _ ....... """ 10-'104 we' ",nd~""'" - "'" downhOle well design is changed. INSTRUCTIONS _" C..,.;r- ~ $eN'" w"" G" _, w."'. ,,,_, W....·"""""'';''I'"'' -, SolI W....-, W."'. Supply fa< _, "",,,,,,,,,",,, """",.. M",,'" """",,,,,, . ""'.... " · ... p""- ,rom """" ~"" "'" """'- production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (ToP of ProduCing Interval). _., ",. KellY......"" ....""""" too< _....." low loW _.. u~ _ .. ...""""" ,,,...... me....M"""" - """",. spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50-029·20123.00-OO). Item 20: True vertical thickness. _ 22 _ ""pie....... M_ ,,, ",... ,_ - "",..- ~ 00,.....1e·- -"og ."'... "",- ~... cementing tool. _ "t ,........ __ ,,, _..'" p""'- 'rom""" ~"" ooe ,,,"'N" ("""". _"~ 00 ",10" """', """ "lie" 23 ,hoW "'" prod_ ""N'" too """... ,meN'" _" """ 26. (Sob"'" ......'" to<m ",..... -- ¡,,_to be separately produced, showing the data pertinent to such interval). lie" "', M""" ~ o,e-' _og, "'" un, Roo P""", "",.~" Po"", ......."""" W...· -, G.. ",¡.,,"", Sh~"', "' Other (explain). Item 27: If no cores taken, indicate "none.". Item 28: List all test informatiOn. If none, state "None". Form 10·407 Revised 4/2003 e e 4/12/2004 9,320 (ft) 7/15/2004 9,320 (ft) 7/16/2004 9,320 (ft) 7/17/2004 9,320 (ft) 7/18/2004 9,320 (ft) 7/19/2004 9,320 (ft) 7/20/2004 9,320 (ft) 7/21/2004 9,320 (ft) 7/22/2004 9,320 (ft) 7/23/2004 9,320 (ft) 7/24/2004 9,320 (ft) 7/25/2004 9,320 (ft) 7/26/2004 9,320 (ft) 7/27/2004 9,320 (ft) RIH with 2.5" OD GR. Run Expro Bond. Start spotting water tanks for frac job. Start hauling water. Haul water to location and offload into frac tanks. Haul water to location and offload into frac tanks. Finish hauling water to location. Start heating water and rigging up additional frac equipment and wellhead scaffolding. Haul frac equiment to location and start rigging up same. Continue heating up frac water. Laid down spill guard material and start berming frac equipment and lines. Continued to rig up flowback test equipment, frac trucks and lines. Completed location rig up. Pressure tested frac lines to 8500 psi and coil tubing and flowback equipment to 4500 psL Perforated module one and pumped into well to verify guns fired. Frac 14 of 15 excape modules. Module 1 tight. Cleaned out all flappers and jetted well in with Coiled Tubing. Commenced well testing operations. Flow test well. Well flowing at 2.6 MMCFD, 648 BWPD, with a FTP of 640 psig on a 46/64 choke. Unload and flow test well. Well making 3.1 MMCFD, 476 BWPD on a 50/64 th choke with a 640 psig FTP. Flow well to test equipment. Well making 3.8 MMCFD, 346 BWPD on a SO/64th choke with a FTP of 630 psig. Cleaned up well to LP production system. LP system developed leak. Switched well to HP production system and continued to clean up and flow test. Continued flowing well to HP production system. At 06007/27/04 well making 3.168 MMCFD, 341 BWD on an open choke with a FTP of 860 psig. ._~.~~_~.~_____ ~_ ___.____M___'___ Printed: 812712004 9:02:13 AM e e MARATHON Oil Company Pad 14-6 KBU23-7 slot #KBU 23-7 Kenai Gas Field Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-9320> svy7022 Date printed Date created Last revised 14-May-2004 19-Feb-2004 14-May-2004 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on n60 27 33.151,wI51 16 7.223 Slot location is n60 27 37.250,wI51 15 46.918 Slot Grid coordinates are N 2362371.636, E 272019.199 Slot local coordinates are 416.30 N 1018.22 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 142.00 202.00 262.00 323.00 384.00 443.00 504.00 564.00 624.00 686.00 745.00 809.00 872.00 935.00 998.00 1060.00 1124.00 1187.00 1249.00 1311.00 1362.00 1435.00 1497.00 1560.00 1623.00 1686.00 1749.00 1811.00 1874.00 1937.00 2000.00 2063.00 2126.00 2189.00 2253.00 2315.00 2380.00 2444.00 2507.00 2571.00 2634.00 2697.00 2761. 00 2824.00 2886.00 2946.00 3009.00 3072.00 3135.00 7.64 8.41 8.98 10.19 11.57 12.58 13.82 15.72 17.73 18.95 20.14 21. 86 23.67 24.70 27.67 30.54 33.12 35.54 37.63 40.20 42.24 44.51 46.91 48.73 50.34 Azimuth True Vert Degrees Depth 0.00 0.52 0.99 1.06 1. 36 0.00 72.99 91. 99 72 .32 71.91 0.00 142.00 201. 99 261.98 322.97 383.95 442.92 503.89 563.86 623.81 685.76 744.70 808.61 871. 54 934.50 997.48 1059.46 1123.46 1186.46 1248.45 1310.45 1361. 45 1434.43 1496.40 1559.25 1621.83 1684.22 1746.49 1807.63 1869.49 1931.10 1992.43 2053.35 2113.68 2173.48 2233.79 2291.67 2351.61 2409.99 2466.52 2522.43 2575.95 2627.97 2679.36 2728.38 2775.01 2818.62 2862.61 2904.91 2945.79 e 5URVEY LI5TING Page 1 Your ref MWD <0-9320> Last revised 14-May-2004 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 5 Deg/l00ft 5ect o .OON o .19N o .25N o .40N o .80N 1.21N 1.67N 2.16N 2.54N 3.07N 3.79N 4.58N 5.59N 6.85N 8.07N 9.04N 9.94N 10.65N 11.34N 12.07N 12.37N 12.00N 10.67N 8.72N 4.57N 2.365 10.875 20.125 30.195 41.785 54.545 68.285 83.345 100.255 118.925 139.235 160.415 184.515 209.785 236.665 266.865 299.195 333.745 370.705 408.815 447.955 487.425 530.595 575.285 621. 335 O.OOW 0.62E 1. 39E 2.44E 3.67E 5.22E 6.90E 8.74E 10 .7 6E 13.00E 15.45E 18.06E 21.20E 23.98E 25.85E 27.14E 27.95E 28.02E 27.82E 27.60E 27.53E 27.76E 28.12E 28.55E 29.69E 31. 53E 33.73E 36.00E 38.29E 40.96E 44.25E 48.47E 54.03E 60.57E 67.23E 73.99E 80.71E 87.89E 94.90E 101.97E 109.49E 117.15E 125.42E 134.85E 145.51E 157.19E 169.04E 182.04E 195.54E 208.83E 0.00 0.37 0.88 0.59 0.49 0.00 -0.01 0.15 0.29 0.25 G RID COO R D 5 Easting Northing 272019.20 272019.82 272020.60 272021.65 272022.88 0.28 0.30 0.34 0.54 0.65 272024.44 272026.13 272027.98 272030.01 272032.26 2362371.64 2362371. 81 2362371.86 2362371.99 2362372.36 2362372.75 2362373.18 2362373.63 2362373.97 2362374.46 2362375.13 2362375.86 2362376.81 2362378.03 2362379.21 2362380.15 2362381.03 2362381.74 2362382.44 2362383.17 2362383.48 2362383.09 2362381.76 2362379.80 2362375.63 2362368.67 2362360.11 2362350.82 2362340.72 2362329.08 2362316.26 2362302.43 2362287.27 2362270.24 2362251.45 2362231.01 2362209.71 2362185.47 2362160.08 2362133.06 2362102.72 2362070.25 2362035.55 2361998.42 2361960.12 2361920.76 2361881.07 2361837.65 2361792.71 2361746.42 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Bottom hole distance is 3770.32 on azimuth 163.97 degrees from wellhead. Vertical section is from wellhead on azimuth 163.93 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1. 66 1. 73 1. 86 2.07 2.33 77.66 71.61 78 .47 80.31 73.37 2.38 2.93 2.97 2.63 1. 43 73.93 72.64 71.68 58.53 53.89 1. 51 0.79 0.57 0.74 0.67 52.45 21. 66 342.90 346.03 338.94 0.13 0.88 1. 31 2.40 5.43 121. 59 151.99 173.11 164.96 164.39 165.69 165.30 167.08 167.29 166.77 164.43 161. 54 158.18 159.44 161.23 161.94 162.83 163.94 165.01 165.52 166.46 166.87 166.22 165.17 163.64 163.13 163.43 163.07 163.32 164.45 0.55 0.33 0.41 0.37 0.62 0.09 0.94 0.10 1.15 1. 92 0.64 0.60 0.50 0.05 -0.60 0.14 1. 49 0.78 0.28 0.18 -1.17 -1. 81 -2.48 -3.20 -3.96 1.25 1. 51 0.80 1. 80 4.81 -4.27 -3.84 -2.47 -0.47 3.83 3.52 1.23 1. 00 1. 95 2.20 11. 00 19.79 29.30 39.61 51. 48 1. 78 2.23 3.31 3.24 2.13 64.66 79.03 95.05 113.10 132.88 1. 90 2.82 2.86 1. 75 4.73 154.28 176.49 201. 64 227.85 255.64 4.54 4.11 3.89 3.41 4.36 286.75 319.93 355.42 393.55 433.11 3.33 3.80 3.83 2.90 2.90 473.96 515.16 560.25 606.93 654.86 272034.71 272037.35 272040.50 272043.31 272045.20 272046.51 272047.33 272047.41 272047.24 272047.02 272046.96 272047.19 272047.52 272047.91 272048.97 272050.67 272052.71 272054.80 272056.90 272059.35 272062.39 272066.35 272071.61 272077.83 272084.12 272090.49 272096.80 272103.52 272110.04 272116.58 272123.53 272130.56 272138.16 272146.88 272156.80 272167.73 272178.82 272190.98 272203.61 272216.02 e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 3198.00 3261. 00 3323.00 3386.00 3448.00 3512.00 3575.00 3637.00 3700.00 3763.00 3826.00 3889.00 3951.00 4014.00 4078.00 4140.00 4202.00 4265.00 4328.00 4391.00 4454.00 4517.00 4580.00 4643.00 4706.00 4769.00 4832.00 4895.00 4957.00 5019.00 5082.00 5146.00 5210.00 5273.00 5336.00 5398.00 5461. 00 5524.00 5586.00 5649.00 5713.00 5776.00 5839.00 5902.00 5966.00 6029.00 6092.00 6154.00 6217.00 6281. 00 52.38 52.86 52.61 52.19 51.89 51. 95 52.40 52.18 51. 93 51. 39 51. 24 51. 03 50.29 50.41 51.52 51. 53 51.17 51. 08 51. 06 50.67 50.17 50.00 50.28 50.38 50.12 49.76 49.61 49.64 49.31 48.62 48.42 47.83 47.49 46.61 46.23 45.29 44.64 44.33 43.56 42.72 42.01 41.19 40.80 40.11 38.66 37.69 36.67 34.93 33.23 31. 65 Azimuth Degrees 165.17 165.77 165.81 166.16 166.12 165.88 166.09 166.33 165.36 166.56 166.48 166.12 165.79 165.77 166.04 165.29 165.99 166.27 166.26 166.13 165.16 165.39 164 .01 162.37 162.39 162.31 162.41 162.67 162.13 162.34 162.15 162.72 162.55 162.29 162.68 163.10 162.79 162.69 163.62 163.47 163.86 162.64 163.22 163.53 164.19 164.38 165.14 164.66 165.07 165.00 True Vert Depth 2985.13 3023.38 3060.92 3099.36 3137.50 3176.97 3215.60 3253.53 3292.27 3331. 35 3370.72 3410.26 3449.56 3489.76 3530.07 3568.64 3607.36 3646.90 3686.49 3726.25 3766.39 3806.82 3847.20 3887.42 3927.70 3968.25 4009.01 4049.82 4090.10 4130.81 4172.54 4215.26 4258.36 4301. 29 4344.72 4387.97 4432.55 4477.49 4522.13 4568.10 4615.39 4662.50 4710.05 4757.99 4807.46 4856.98 4907.18 4957.46 5009.64 5063.65 e SURVEY LISTING Page 2 Your ref MWD <0-9320> Last revised : 14-May-2004 R E C TAN G U L A R Dogleg COO R DIN ATE 5 Deg!100ft 668.82S 717.28S 765.11S 813.54S 861. OOS 909.885 958.16S 1005.805 1053.97S 1101.90S 1149.73S 1197.38S 1243.90S 1290.92S 1339.14S 1386.165 1433.075 1480.69S 1528.29S 1575.75S 1622.795 1669.52S 1716.175 1762.58S 1808.75S 1854.705 1900.48S 1946.26S 1991.185 2035.725 2080.67S 2126.10S 2171.25S 2215.215 2258.735 2301.185 2343.74S 2385.905 2427.08S 2468.39S 2509.785 2549.835 2589.345 2628.50S 2667.51S 2704.995 2741.72S 2776.74S 2810.815 2843.98S 221.72E 234.28E 246.39E 258.48E 270.19E 282.38E 294.43E 306.12E 318.27E 330.26E 341.72E 353.34E 364.98E 376.89E 389.00E 401. 02E 413.03E 424.78E 436.42E 448.08E 460.12E 472.40E 485.16E 499.18E 513.85E 528.47E 543.02E 557.42E 571. 67E 585.94E 600.34E 614.72E 628.84E 642.76E 656.50E 669.57E 682.62E 695.72E 708.19E 720.39E 732.53E 744.58E 756.71E 768.40E 779.70E 790.24E 800.25E 809.70E 818.92E 827.78E 3.36 1.07 0.41 0.80 0.49 704.06 754.10 803.42 853.30 902.15 Vert Sect G RID Easting COORDS Northing 2361698.70 2361650.01 2361601. 95 2361553.30 2361505.63 2361456.52 2361408.02 2361360.17 2361311.77 2361263.62 2361215.59 2361167.72 2361120.98 2361073.74 2361025.31 2360978.06 2360930.93 2360883.10 2360835.28 2360787.61 2360740.35 2360693.39 2360646.51 2360599.83 2360553.40 2360507.18 2360461.13 2360415.08 2360369.89 2360325.09 2360279.87 2360234.17 2360188.76 2360144.55 2360100.77 2360058.08 2360015.27 2359972.87 2359931.46 2359889.92 2359848.31 2359808.04 2359768.31 2359728.92 2359689.71 2359652.03 2359615.11 2359579.93 2359545.68 2359512.35 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level: Bottom hole distance is 3770.32 on azimuth 163.97 degrees from wellhead. Vertical section is from wellhead on azimuth 163.93 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.31 0.76 0.47 1.28 1.72 952.49 1002.22 1051. 23 1100.89 1150.27 0.26 0.56 1. 26 0.19 1. 77 1199.39 1248.41 1296.33 1344.81 1394.49 0.95 1.06 0.37 0.03 0.64 1443.01 1491.40 1540.41 1589.38 1638.21 1.43 0.39 1. 74 2.01 0.41 1686.74 1735.05 1783.40 1831. 89 1880.31 0.58 0.27 0.32 0.85 1.14 1928.51 1976.53 2024.51 2071. 62 2118.37 0.39 1.14 0.57 1.43 0.75 2165.54 2213 .18 2260.48 2306.57 2352.20 1. 59 1. 09 0.50 1. 62 1.34 2396.61 2441.12 2485.26 2528.28 2571. 35 1.18 1. 83 0.86 1.14 2.36 2614.48 2656.30 2697.62 2738.50 2779.11 1.55 1. 78 2.84 2.72 2.47 2818.04 2856.11 2892.37 2927.67 2961.99 272227.99 272239.61 272250.80 272261.95 272272.75 272283.99 272295.11 272305.88 272317.10 272328.16 272338.70 272349.40 272360.13 272371.14 272382.31 272393.42 272404.53 272415.36 272426.08 272436.82 272447.95 272459.33 272471.19 272484.32 272498.09 272511 .82 272525.49 272539.01 272552.39 272565.80 272579.32 272592.82 272606.07 272619.15 272632.04 272644.29 272656.52 272668.81 272680.48 272691. 88 272703.21 272714.49 272725.86 272736.80 272747.33 272757.16 272766.46 272775.23 272783.79 272792.01 e e MARATHON Oil Company SURVEY LISTING Page 3 Pad 14-6,KBU23-7 Your ref MWD <0-9320> Kenai Gas Field,Kenai Peninsula, Alaska Last revised 14-May-2004 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C OORDS Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 6344.00 30.43 164.88 5117.63 2875.35S 836.22E 1. 94 2994.47 272799.84 2359480.83 6406.00 28.83 165.06 5171.52 2904.95S 844.17E 2.58 3025.12 272807.22 2359451.08 6469.00 27.02 165.12 5227.18 2933.46S 851.76E 2.87 3054.61 272814.26 2359422.43 6590.00 25.41 167.34 5335.73 2985.36S 864.51E 1.56 3108.01 272826.01 2359370.30 6652.00 25.30 167.36 5391.76 3011.26S 870.33E 0.18 3134.51 272831.32 2359344.29 6715.00 24.39 167.09 5448.93 3037.08S 876.18E 1. 46 3160.94 272836.68 2359318.37 6778.00 23.75 166.91 5506.45 3062.11S 881. 96E 1. 02 3186.60 272841. 97 2359293.22 6842.00 23.67 166.07 5565.05 3087.14S 887.97E 0.54 3212.30 272847.50 2359268.09 6904.00 22.65 166.83 5622.05 3110.84S 893.68E 1. 71 3236.66 272852.76 2359244.28 6968.00 21. 89 166.64 5681. 28 3134.45S 899.25E 1.19 3260.89 272857.87 2359220.57 7031.00 21. 58 166.56 5739.80 3157.14S 904.66E 0.49 3284.19 272862.84 2359197.78 7093.00 21.47 166.01 5797.47 3179.24S 910.05E 0.37 3306.92 272867.80 2359175.58 7157.00 21.14 165.92 5857.10 3201. 80S 915.69E 0.52 3330.16 272873.01 2359152.92 7220.00 20.87 165.47 5915.91 3223.69S 921. 27E 0.50 3352.73 272878.16 2359130.93 7282.00 20.62 165.94 5973.89 3244.97S 926.69E 0.48 3374.68 272883.17 2359109.55 7344.00 20.27 165.83 6031. 99 3265.97S 931.97E 0.57 3396.33 272888.05 2359088.45 7406.00 20.05 165.15 6090.19 3286.66S 937.32E 0.52 3417.69 272893.00 2359067.67 7470.00 19.70 165.23 6150.38 3307.69S 942.89E 0.55 3439.44 272898.16 2359046.53 7533.00 18.92 165.03 6209.83 3327.83S 948.23E 1.24 3460.27 272903.11 2359026.30 7597.00 18.29 163.71 6270.49 3347.49S 953.73E 1.18 3480.69 272908.23 2359006.53 7660.00 17.27 163.96 6330.48 3365.97S 959.09E 1. 62 3499.92 272913.23 2358987.96 7723.00 16.48 162.91 6390.77 3383.49S 964.30E 1. 34 3518.21 272918.10 2358970.33 7786.00 16.08 162.41 6451. 24 3400.35S 969.56E 0.67 3535.87 272923.04 2358953.37 7848.00 15.90 163.27 6510.84 3416.67S 974.60E 0.48 3552.94 272927.76 2358936.96 7911.00 15.00 163.55 6571. 56 3432.76S 979.39E 1.43 3569.72 272932.24 2358920.79 7973.00 13.25 164.09 6631. 69 3447.28S 983.61E 2.83 3584.85 272936.18 2358906.18 8037.00 11.78 164.82 6694.16 3460.64S 987.33E 2.31 3598.72 272939.65 2358892.75 8100.00 10.83 164.59 6755.94 3472.56S 990.59E 1. 51 3611. 07 272942.67 2358880.78 8163.00 10.06 163.70 6817.90 3483.54S 993.71E 1.25 3622.49 272945.58 2358869.74 8226.00 9.90 163.62 6879.94 3494.02S 996.78E 0.25 3633.41 272948.45 2358859.20 8290.00 9.04 163.44 6943.07 3504.12S 999.76E 1.34 3643.94 272951.24 2358849.05 8353.00 8.42 163.74 7005.34 3513.29S 1002.47E 0.99 3653.50 272953.76 2358839.83 8416.00 8.15 162.91 7067.68 3521.99S 1005.07E 0.47 3662.58 272956.20 2358831.08 8479.00 7.97 162.98 7130.06 3530.43S 1007.66E 0.29 3671.41 272958.63 2358822.59 8542.00 7.53 161. 93 7192.49 3538.53S 1010.22E 0.73 3679.90 272961.03 2358814.44 8605.00 7.34 162.08 7254.96 3546.29S 1012.74E 0.30 3688.05 272963.40 2358806.64 8668.00 7.28 162.13 7317.44 3553.91S 1015.20E 0.10 3696.06 272965.71 2358798.97 8732.00 7.22 161.38 7380.93 3561. 59S 1017.73E 0.18 3704.13 272968.09 2358791.25 8793.00 6.96 159.28 7441.47 3568.67S 1020.26E 0.60 3711.65 272970.49 2358784.11 8856.00 6.92 161. 21 7504.00 3575.84S 1022.83E 0.38 3719.24 272 972.92 2358776.90 8919.00 6.55 160.37 7566.57 3582.81S 1025.26E 0.61 3726.62 272975.22 2358769.88 8982.00 6.69 161. 23 7629.15 3589.67S 1027.65E 0.27 3733.87 272977 .47 2358762.98 9043.00 6.39 160.78 7689.75 3596.24S 1029.91E 0.50 3740.81 272979.60 2358756.37 9106.00 6.14 159.96 7752.38 3602.72S 1032.22E 0.42 3747.67 272981. 79 2358749.85 9181. 00 6.04 157.01 7826.95 3610.12S 1035.14E 0.44 3755.59 272984.56 2358742.39 9266.00 6.16 157.39 7911.47 3618.45S 1038.64E 0.15 3764.56 272987.90 2358734.00 9320.00 6.16 157.39 7965.16 3623.80S 1040.86E 0.00 3770.32 272990.02 2358728.61 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level) Bottom hole distance is 3770.32 on azimuth 163.97 degrees from wellhead. Vertical section is from wellhead on azimuth 163.93 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 Pad l4-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 9320.00 7965.16 Top MD Top TVD Rectangular Coords. 3623.80S Rectangular Coords. e SURVEY LISTING Page 4 Your ref MWD <0-9320> Last revised : l4-May-2004 Comment Comments in wellpath -------------------- -------------------- 1040.86E Projection to TD Casing positions in string lA' --------~--------------------- ------------------------------ 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.oow O.OOw O.OOW O.OOW 121. 00 1395.00 6548.00 9320.00 121.00 1394.44 5297.88 7965.16 o .14N 11. 48N 2967.62S 3623.80S Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location T.V.D. 0.45E 27.97E 860.40E 1040.86E 3547.05S 3054.00S Rectangular Coordinates 1017.06E 880.00E 20" Conductor 13 3/8" 9 5/8" 3 1/2" Revised ----------------------------------------------------------------------------------------------------------- 6-Nov-2003 6-Nov-2003 KBU237 - TD Tgt - Rv KBU237 - TIMid Belug 7725.00 5340.00 e e 2/15/2004 (ft) 2/16/2004 (ft) 2/17/2004 (ft) 2/18/2004 1,060 (ft) 2/19/2004 1,405 (ft) 2/20/2004 1,405 (ft) 2/21/2004 1,405 (ft) 2/22/2004 2,633 (ft) 2/23/2004 3,510 (ft) 2/24/2004 5,040 (ft) 2/25/2004 5,962 (ft) 2/26/2004 6,547 (ft) 2/27/2004 6,547 (ft) 2/28/2004 6,547 (ft) 2/29/2004 6,547 (ft) 3/1/2004 6,567 (ft) 3/2/2004 7,645 (ft) 3/3/2004 8,000 (ft) 3/4/2004 9,015 (ft) MOB and begin RIU Glacier Drilling rig #1 onto well KBU 23-7 MOB - RIU Glacier Drilling Rig #1 Complete MOB and RIU. N/U and test diverter. P/U DP. Wash out drive pipe to 121'. Drill f/121' to 1060'. Wiper trip. TBIH to TO 1060' Drill f/1060' to casing point 1,405'. CBU. Wiper trip. CBU. TOOH for casing. RIH 13 3/8 csg, WO equip, RIH 5" sting in assy RIH stab in assy, cmt 13 3/8 csg, POH, N/D, N/U BOPE Test BOPE, PU DP, MU drctnl assy, RIH, C/C, clean flow line. Drill 1370 ft, test csg, drill 1425, LOT, drill 1433, repair flowline, drill 2440, wiper trip, drill to 2633 ft Drill to 3448, circ, wiper trip, drill to 3510, POH for washout, RIH, re-torque connections eire, drill to 4514, wiper trip, drill to 5040 Drill to 5521, wiper trip, ser rig, drill to 5962 Drill to 6547, C/C CIC, POH wiper trip, ser rig, cut drlg line, RIH wiper trip, C/C, wiper trip, C/C, POH for csg. POH, LD BHA, change rams, test, RU I run 9 5/8 csg Cont RIH 9 5/8 csg, circ, regain lost circ, cmt, prepare test BOPE Change rams, cut drlg line, install pkf, test, test BOPE, M/U BHA, P/U 5" DP, drill float collar, test csg, drill shoe /20 new fmtn, displace drlg fluids, Displace well new fluids, LOT, drill ahead, repair Epoch, drill ahead Drill 7712, POH wiper trip, ser rig, RIH wiper trip, drill 7900, POH for MWD, RIH new MWD, drill to 8000 ft Drill ahead 8 1/2 hole to 9015 Printed: 5/1712004 2:02: 15 PM e e 3/5/2004 9,320 (ft) 9,320 (ft) Drill 9079, CBU, drill 9320, eire, wiper trip, ser rig, circ, POH for logs 3/6/2004 POH, E-Iog Printed: 5/17/2004 2:02: 15 PM e e 3/6/2004 9,320 (ft) 31712004 9,320 (ft) 3/8/2004 9,320 (ft) 3/9/2004 9,320 (ft) 3/1 0/2004 9,320 (ft) M/U BHA, RIH 6547, cut drlg line, ser rig, MOC evaluate E-Iogs, RIH 6547, C/C Circ, POH laying dn 5" DP, run Excape compo Run Excape comp, CBU, wireline correlation, emt, nipple dn N/D BOPE, suspend tbg, install control lines / pkf, N/U tree, test, RID. Rig dn, prepare for move to KBU 33-6, release rig ~_.~..._._~- Printed: 5/17/2004 2:02:29 PM API: 50-133-20532-00-00 RT -GL: 21.00' RT-THF: 21.00' 317' FSL, 1105' FWL, Sec. 6, T4N, R11W, S.M. Tree cxn = 4-3/4" Otis ITOC (est) - ???' ExcaDe Svstem Details - BHP monitoring line volume tank located from 6584' - 6619' RKB KBU 23..7 Excape SyStem Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 1 - NA Module 2 - 8750' Module 3 - 8675' Module 4 - 8156' Module 5 - 7901' Module 6 - 7563' Module 7 - 7461' Module 8 - 7318' Module 9 - 7252' Module 10 - 7109' Module 11 - 7001' Module 12 6951' Module 13 - 6912' Module 14 - 6757' Module 15 - 6689' P: Dated Completed: Prepared By: TD - 9320' PBTD - 9230' KBU 23-7 Kenai Surface Casino: 13-3/8", 68 ppf,K-55, @ 1395 Cmt w/ 398 sks oftype 1 at 12 ppg IntCasinQ: 9-5/8", 47 ppf, L.-80, BTC.@ 6547' Cmt w/ 842 sks of class G at 13.5 ppg Prod. Tubino: 3-1/2", 9.3 ppf, L-80, EUE8rd with 6.25" OD control line protectors to 92$8' Cmt w/1147 sks of class G at 15.8 ppg Excape System Details - 15 Excape modules placed - Veil oW control line fires bottom 1· module - Green control line fires middle 6 modules - Red control line fires top 8 modules - Ceramic flapper valves below each module Perfs MD (RKB): Module 1 - 9183-9193' Module 2 - 8738-8747' Module 3 - 8661-8671' Module 4 - 8144-8154' Module 5 - 7890-7900' Module 6 - 7553-7563' Module 7 - 7451-7461' Module 8 - 7311-7321' Module 9 - 7243-7253' Module 10 - 7098-7108' Module 11 - 6990-7000' Module 12 - 6939-6949' Module 13 - 6900-6910' Module 14 - 6748-6758' Module 15 - 6678-6688' Alaska (TV!:) 6% KCL Completion Fluid: BHT: 3/10/2004 J. R. Thompson 5/19/2004 Last Revison Date: . . Winton, As per our conversation this morning, we are requesting a change in the BOP test pressure for Glacier #1 on KBU 23-7 from 3,500 psi to 3,000 psi. This is due to the fact that the upper most flange of the multi-bowl wellhead is rated to only 3,000 psi. The test plug for testing the stack is set in a profile below this upper flange. That flange is exposed to the BOP test pressure. In looking at the calculated MASP for each hole section, no pressures are expected above 2,844 psi, so 3,000 psi should cover any possible maximum pressure we would see during the drilling operations. If you have any questions or comments, please give me a call. Thanks, Will Tank Senior Drilling Engineer Marathon Oil Company (907)564-6310 -- -- FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA OILAl'fD GAS CONSERVATION COMMISSION David R. Castillo Sr. Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519 333 W. ]TH AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field KBU 23-7 Marathon Oil Company Permit No: 203-217 Surface Location: 317' FSL, 1105' FWL, Sec. 6, T4N, RllW Bottomhole Location: 3235' FNL, 2122' FWL, Sec. 7, T4N, RllW Dear Mr. Castillo: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the pennit. 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). , BY ORDER OF THE COMMISSION DATED thislL day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. e . Alaska Region Domestic Production Marathon Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 15, 2003 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Permit to Drill Application Field: Kenai Gas Field Well: Kenai Beluga Unit 23-7 / Dear Ms. Palin, Enclosed please find a PERMIT TO DRILL application, along with the associated attachments for the Kenai Beluga Unit 23-7. 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. If you require further information, please contact me. Sincerely, &~t~ David R. Castillo Senior Drilling Engineer Telephone: 907-564-6465 Email: DRCastillo@MarathonOil.com RECEIVED DEC 152003 Alaska Oil & Gas Cons, Commission Anchorage O~\G\NAL j,UC:¡t\ I Ll liP (2-00š e - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: DrillŒJ RedrillD 1 b. Current Well Class: Exploratory 0 Development Oil 0 Multiple zoneŒJ Re-entry 0 Stratigraphic TestD Service 0 Development Gas ŒJ /singlezoneD 2. Operator 5. Bond: ŒJBlanket 0 Single Well 0 11. Well Name and Number: Name: Marathon Oil Company KBU 23-7 /' Bond No. 5194234 3. Address: P.O. Box 196168 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99519-6168 MD: 9113.53ft TVD: 7725ft Kenai Gas Field 4a. Location of Well (Governmental Section): 7. Property Designation: Beluga Pool A-D28142 Surface: 317' FSL 1105' FWL Sec. 6 T4N R11W 8. Land Use Permit: 13. Approximate 25-Feb-04 / NIA Spud Date: Top of Productive Horizon: 2741' FNL 1985' FWL Sec. 7 T4N R11W 9. Acres in Property: 14. Distance to 2345 acres Nearest Property: otal Depth: 3235' FNL 2122' FWL Sec.7 T4N R11W 2100ft 4b. Location of Well (State Base Plane Coordinates): 10. KB elevation 15. Distance to Nearest RKB-MSL 86.6 feet Well within Pool: 1658ft Surface: x- 272019.199 v- 2362371.636 Zone- 4 (Height Above GL): 21 feet KDU 4 Top of Middle BeluQa 16. Deviated Wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff Depth: 1500 ft. Maximum Hole Angle: 50.450 Max. Downhole Pressure: 3612 psig. Max. Surface Pressure: 2844 ~i9. 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including Stage Data) 26 in. 20 in. 133 K-55 BTC 100ft 0 0 100ft 100ft NIA 16 in. 13318 in. 68 K-55 BTC 1400ft 0 0 1400ft 1399ft 365 sacks 121/4 in. 9518 in. 40 L-80 BTC 6588ft 0 0 6588ft 5297ft 831 sacks 81/2 in. 31/2 in. 9.3 L-80 8rd 9113ft 0 0 9113ft 7725ft 1201 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 Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing FeeD BOP Sketch 0 Drilling ProgramD Timev. Depth PlotD Shallow Hazard Analysis 0 Property PlatO Diverter Sketch 0 Seabed ReportD Drilling Fluid ProgramD 20 AAC 25.050 Requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name David R. Castillo Title Senior Drilling Engineer l ,_ .1/ f) ~ ' /JA IS~o5 Signature Phone 907-564-6465 Date Commission Use Only Permit to Drill ..2..17 I~PI Number: .2 0 5.3 .::2- I ~ermit Approval fZJJ1101 I ~ee cover letter for Number: ..z 0 3 - 50- /J3 - Date: other requirements. Conditions of approval: Samples required DYes JZI No Mud log required I DYes J:8I No Other:T e. s+- Hydrogen sulfide measures DYes ~NO Directional survey required ~Yes DNo ße) P E f-o '~5~D f£' ì . RECEIVED Original Signea Iv BY ORDER OF IzJ J 1ltirKr. 1 p; 1001 Approved bv: COMMISSIONER THE COMMISSION Date: ....,n , -- Alaska Oil & Gas Cons. Commission Anchorage OR\G\!\JA\ e e MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM KBU 23-7 PERMIT December 15, 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 BOP E Program....................................................................................................................... .................................................6 Directional Program Summary.................................................................................................................................... ............7 Directional Surveying Summary ................................................................................................................................... ...........7 Drilling Fluid Program Summary.................................................................................................................................... .........8 Drill ing Flu id 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 Kenai Gas Field Kenai Borough Alaska 9114 ft 7725 ft NA DD.03.09625.CAP.DRL 25-Feb-04 NA Development Inlet Drilling Glacier 1 / KBU 23-7 X: 2362371.6360 Kenai Pad 14-6 21 ft 65.6 ft RKB NA 1300 V: 272019.1990 Comments: Geoloaic Proaram Summary Top Sterling 4011 3500 140-1,190 0.76-6.5 Sandstone Gas I Water Top Beluga 5842 4697 375-1,784 1.53-7.3 Sandstone Gas Top Middle Beluga 6638 5340 1,068-2,456 3.85-9.0 Sandstone Gas JD.O Top Tyonek 8616 7227 2,168-3,397 5.77-9.0 Sandstone Gas Comments: / Township 4N, Range 11W Seward N 600 27" 37.250" W 151015" 46.918" 2362371.6360 272019.1990 NAD27 ASP ZONE 4 272967.70 E 2358805.80 N Comments: page 1 of 10 e e Summary of Potential Drillina Hazards Lost Circulation The Sterling sands are approximately 0.04 psi/ft to 0.34 psi/ft and 400-md perm. The Upper Beluga intervals have SBHP's estimated at 400 psi that is a range from a 0.08-.38 psi/ft. The Tyonek could range from 0.3 psi/ft to 0.47 psilft. Pre-treat mud with sized Calcium Carbonate. Control losses by using sufficiently sized LCM. See comment above about the Sterling, Beluga, and Tyonek intervals. Keep the drill pipe moving and avoid if possible excess overbalance. Maintain low fluid loss and thin impermeable filter cake. Circulate hole dean before tripping. Do not POOH or RIH faster than 30 see/stand Differential Sticking SurgelSwabbing 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 or BLM inspector. 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 Sterling at +1- 4,011 ft MD RKB (3500 ft TVD RKB) to total depth of the well. These sands will run from normal pressured to severely depleted and lost circulation and differential sticking are potential hazards. The FloPro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. . ~~.; ~ The KBU ~will be directionally nudged at 500 ft away from the KU21-7 wellpath with the closet approach of 50 ft at 1400 ft. MD. The KDU-4RD from pad 41-7 will approach to within 622 ft at 8860 ft MD. Formation Evaluation Summary Surface None o ft - 1,400 ft MD Intermediate None 1,400 - 6,588 ft MD Production None 6,588 - 9,114 ft MD Completion NIA None Rig WatchlBasic Cased hole- Gamma RaylNeutron to top of Sterling at 4011 ft Rig Watch/Basic Reeves - Quad Combo Basic with GCA, shale density, temperature in and out, sample collection (10' samples). GRlNeutron, eeL NIA Coring Requirements: None Comments: page 2 of 10 e e Drillina Proaram Summary CONDUCTOR: 1. Drive 20" conductor to +1- 100 ft. RKB. 2. Move in and rig up Glacier #1 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. 2. Drill a 16" hole to 1400 ft (1399 ft TVD) with Spud Mud. RIH with 133/8" casing and hang off in the slips. Make up stab-in sub and centralizer on 5" 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. PU 133/8" casing, set casing slips in 20", cut off 13 3/8", ND diverter. Install 13 3/8" slip lock connection X 13 %" 5M flanged multibowl wellhead./ NU 13 %" 5M BOP'S. Test BOP'S and choke manifold to 250/3,500 psi. Set wear bushing. . Test surface casing to 2,000 psi. / 3. 4. 5. 6. 7. 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 6588 ft MD (5297 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 250/3,500 psi. Run and cement 9 %" casing. Land hanger in multibowl wellhead. Back out landing joint. Change out 9 %" BOP c¿t5ing rams with variable pipe rams. Run test plug and test BOP pipe rams to 250/3,500 psi. / Set wear bushing. Test casing to 2,000 psi. 9. PRODUCTION: 1. Pick-up ±2750 ft of 4" DP 2. Drill float equipment and 20' of new formation with an 8 y,." bit. Circulate mud until mud weight in equals mud weight out.. 3. Test shoe to leak-off. Estimated EMW 15.01 ppg. ___. 4. Drill an 8 y,." hole to 9114 ft MD RKB (7725 ft TVD) per the directional program. 5. TOOH. RU logging company. Run open hole logs as per plan. RD logging company. 6. TIH to TD for wiper trip. TOOH and lay-down BHA and drill pipe. Pull the wear bushing. /. 7. Run 3 y,." EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging company. 8. Cement 3 y,." casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. 9. PU 3 y,." casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 3 Yo" casing. /' 10. LD BOP. Set 3 Yo" packoff. NU 13 %" 5M X 3 Ye" 5M tubing head adapter and 3 Ye" 5M tree. Test tree to 5,000 psi. 11. Rig down and move out drilling rig. Note: Perforating guns will be run on the outside of the 3 Yo" production casing with a flapper valve just below each perforating gun. Guns to be activated by control line to surface. COMPLETION: Completion will be done without a rig. page 3 of 10 e e Casina Proaram 20 0 100 133 K-55 18.73 18.543 Welded NA NA Driven 3056 1496 2125 13 3/8 0 1400 68 K-55 12.415 12.259 BTC 14.375 Diamond 16 3454 1949 1069 95/8 0 6588 40 L-80 8.835 8.75 BTC 10.625 Diamond 12 1/4 5745 3087 916 31/2 0 9114 9.3 L-80 2.992 2.867 8rd 4.5 3,200 81/2 10160 10535 207 Comments: Casina Desian 20 130.1 K-55 100 8.6 12.00 8.4 NA + 100 33.52 24.76 ~ 13% 68 K-55 1399 9.0 14.53 8.4 916 3.45 2.98 2.56 9% 40 L-80 5297 9.4 15.01 8.58 1915 1.15 1.19 2.64 3% 9.3 L-80 7225 9.6 15.70 9.0 2844 1.29 2.74 1.70 Comments: Maximum Anticipated Suñace Pressure 13 % 9% 1399 5297 2705 4431 916 70/30 70/30 0/100 3 % 7725 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:= 1399·ft TVDOH := 5296- ft F mud := 30% FG := 14.53·ppg pSI Pgas:= O.l·ft Pmud := 9.4·ppg MASP frac := FG· TVDShoe - (p gas· TVDShoe) MASP frac = 916 psi BHP:= PP·TVDOH MASPbhp := BHP - (Fmud·TVDOH·Pmud) - [( 1- Fmud)·TVDORPgaJ MASPbhp = 1214psi MASP := mi~ MASP frac' MASP bhp) MASP = 916psi 95/8" Intermediate Casinq TVDShoe:= 5297·ft TVDOH := 7725·ft Pmud := 9.60·ppg FG := 15.01·ppg pSI P gas := O.l·ft F mud := 30% MASP frac := FG· TVDShoe - (p gas' TVDShoJ MASP frac =&Si BHP:= PP.TVDOH BHP = 3612psi MASPbhp := BHP - (Fmud·TVDORPmud) - (1 - Fmud)·TVDORPgas MASPbhp = 1915psi MASP := mi~MASP frac,MASPbhp) MASP = 1915psi page 5 of 10 e PP := 8.58·ppg PP:= 9.0·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 PP := 9.0·ppg TVDShoe:= 7725·ft MASP := ( Cr P gas' TVDShoe) + (C2· pp. TVDShoe) + C3 MASP = 2844 psi // BOPE Proaram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Surface 13% 2705 916 2000 9 (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 (1) 13-5/8" 5M pipe ram Intermediate 9% 4431 1915 2000 9.4 (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-518" 5M annular ./ / (1) 13-518" 5M pipe ram Production 3% 5000 2844 2000 9.6 (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets 250/3500 / 250/3500 250/3500 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 13-518" x 5000 psi drilling spool (mud cross) with 3-118" 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. Z. ':)000 p~ : "-0 W~V€...r ~.ÓLAJ ~.d. page 6 of 10 e e Wellhead Equipment Summary Tubing Head 13-%" 3M Studded Bottom X 13-%" 5M Fig Top, W/2, 2-1/16" 5M Studded Outlets, U,AA,PSL 1,PR1 13 %" x 9 %" Fluted Mandrel 13 %" x 3 Yo" Manual Slip / Casing Head 13-%" 3M X 13-3/8" Slip Loc WI 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, PR1 Adapter Flange 13-%" 5M X 3- Yo" 5M WI Seal Pocket and 3" H BPV Threads Comments: Directional Proaram Summary 0 0 0 0 0 0 0 0 0 0 Nudge 500 500 2 0 0 0 64 0 0 0 End Nudge 750 749.68 0 0 2 5.0 64 4.78 N 9.8 E -1.88 Drop 850 849.3 -2 0 2 5.0 64 8.60 N 17.63 E -3.38 EOD 1100 1098.99 0 0 0 0 164.45 13.38 N 24.73 E -5.26 KOP 1500 1498.99 0 0 0 0 164.45 13.38 N 24.73 E -5.26 EOC 3181.66 3174.32 3 0 3 50.45 164.47 655.03 S 213.21 E 688.46 Drop 5275.07 4304.60 0 0 0 50.45 164.47 2210.24 S 645.47 E 2302.54 EOD 8638.39 7249.86 -1.5 0 1.5 0 164.4 7 3547.05 S 1017.06 E 3689.98 TD 9113.53 7725.00 0 0 0 0 164.47 3547.05 S 1017.06 E 3689.98 Comments: Directional Survevina Summary o - 1 ,400 ft X 1,400 - 6,588 ft X 6,588 - 9,114 ft X Comments: page 7 of 10 e e Drillina Fluid Proaram Summary 6588 9114 Flo-Pro wI 6% + 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 1400 6588 Flo-Pro wI 6% KCL + Safecarb Comments: Drillina Fluid Specifications 0 1400 8.6 - 9.2 60-100 25-35 NC-12 ±9.5 <7% 1400 3500 9.0 - 9.4 8-12 40,000 8-10 ±9.5 ±5% 3500 6588 9.2 - 9.6 10-14 40,000 7-9 ±9.5 ±8% 6588 9114 9.0 - 10.0 10-14 40,000 <5 ±9.5 ±5% Comments: Mllntegrated Fluids Engineering Plan, Dee 10th, 2003 Solids Control Equipment 1 - Derrick Model 0522 2 - Ml/Swaco units 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 Proaram Summary 13% 9% 1400 6588.39 9113.53 1398.99 5296.86 7725 12 Y. 16 o 3511.47 6138.39 o 3181.62 4924.56 641 963 987 914 1462 1405 50% 50% 50% 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. 9% Class "G" 13.5 15.8 831 1201 1.76 1.17 1462 3512 1405 6139 8.35 5.03 Fresh Fresh 10 18 o o 13.5 hr 6hr 911 2431 3Y:. Class "G" Comments: BJ Proposal100182146A, Dec 8th, 2003 Reaulatorv 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 KBU 23-7. 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 3 1/2" 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 an offset well on this pad BC 11 on 1/15/2003 and was granted. No problems were encountered while doing this operation on the above well this year. ,..rJM\I.dj T~c,. t- -t, SÇOc.? fSÆ - vW ~ -y ~r..s.~"'l ! page 9 of 10 e e Hvdraulics Summary Rig mud pumps available are shown below. 3 National Oil Well A600PT 5 5 5 8 8 8 2,597 2,597 2,597 2.04 2.04 2.04 175/357 175/357 175/357 Surface Intermediate Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. 1 - 12 1400 16 690 2200 60 9.2 1 - 14 Wellplan 2000 Hydraulics 2 -165 6588 3 - 18s Wellplan 2000 Hydraulics 12.25 690 2200 60 9.6 1 -15 9113 8.5 487 2400 60 10.1 4-155 Well plan 2000 Hydraulics Comments: Assume 5" drill pipe in the 16" and 12 %" hole section. Formation Integritv 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 10 of 10 121 1/4" 2M Diverter 1---. 1 Diverter Spool e Marathon Oil Well BC-12 Diverter e Flow line 1 ~ / 116" Automatic ~¡ '= ~ \ L- 116" Diverter Line I Knife Valve / e FIOWNipple ---. 13 5/8" 5M Annular Preventer . Marathon Oil Well BC-12 BOP Stack I Pipe Ram I Blind Ram ~~ [[[]]]0I1illIII0IIJ Œ[] 135/8"5MCross I ~ 13 5/8" 5M Double Ram Preventer ------. 21/16" 5M Manually Operated Valves I Choke I e I Flow Line I \ 3 1/8" 5M Manually Operated Valve '1..r ~ 3 1/8" 5M Manually Operated Valve t 3 1/8" 5M Hydraulically Operated Valve e Marathon Oil Well BC-12 Choke Manifold e / ITa Gas Buster t Bleed off Line to Shakers ~ I~P C ~ ~ q~ 13" 5M Valves i 29/16" 10M Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke I From BOP Stack e F e I 1 I L________ I I I I I I I I I t ".....-......, I/~\ I~...~ I,----v ! ,...__,1 ~-----i ~-----l~ í ! L__.J II J I 1 I I ..--, q I I I II r : I I !! I I I fe¡' I ¡III ~ t I II I I i!i " I II 1 ,I II I 1 ~ I I ~ U I I!!i I I I!!i II I r1-====.:!--,L-----..J I ".,,,., I I : ....,... -,...! I .... r-----¡ I I I I ŒNTRIFUG£j I UNIT I I 4' )( 10' I I I I I I I I I I DlJf> I 1 /-, I .....1' I I I L.__.___.J ICDt1HY 3' X 12' j II I /I 75 HP 615 U· ...- IIE&IaEII .~ - ...... 75tP 6)(5 U' ~ \. 75 HP fi X :5 U' I~I GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT ..... Î'I :IV 9L 11-600 ~T 75tP 6 II :! II" I I I- !l I.::. I 5\/ 9L ,41-6110 PT r- I I T --, ~ I ~ 1m.... , æ 1m.. I 13'..... ~ ì ~., n1ii'I ~ - ~.~ fI ... I'IJ. Pn' SURF. USE PLAN FOR KENAI UNIT K.23-7 Surface Location: NW 1/4 of SW 1/4, Sec. 6, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KBU 23-7 are shown on the attached map. Kenai, Alaska, is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access KBU 23-7. 3. Location of Existing Wells Well KBU 23-7 will on pad 14-6. A pad drawing is attached that shows existing wells. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. A flowline will be installed from the KBU 23-7 wellhead to an existing heater. A new separator will be installed in an existing building to handle the additional gas. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 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 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II 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). F:\Permanent\MILES\Projects\Kenai\KGF Pad 14- 6\KBU 23-7\Permits\Surface Use.doc Surface Use Plan e Kenai Unit KBU 23-7 e Page 2 d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Kenai Unit KBU 23-7 will be re-drilled from an existing pad. Reclamation of the pad will occur after abandonment of KBU 23-7 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CIRI Native Corporation prior to any reclamation work beginning. 10. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. 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 15, 2003 David R. Castillo Sr. Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6465 ABREVEATION5, OHE. = OVERI-4EAP ELECTRIC OH PIW = OVERI-4EAD PIPEWAY ::E '" u '" m i < '" o ::E fJ ::E '" m o '" '" u '" :I: U è:> o . .;.¡ -' ð fJ N '" o :I: ê . ~ < u fJ ,.; ~ - o f- '" '" :I: fJ i '" E X .. .. . ,. ~ ì! .. ¡¡ r Z 1 & )(.~.~.3Ð 12 1 Y-1>62,Ð'W.ÐI + ....,;>b,øeÐ_~ 04-. 'Æ;:r~~ ~""~ ~ 8.Ð'X12.Ð' UTIJ../TY ..æ:ATEIIiI "'-DC>. ðURYEy UION< LINE N 8'3.IZ)Ø'~. W e5C0.31' CONe. po""" !!I n-----~~~ D_ ,.2'><S.J' !"ETA!.. K.U. 4~-12 :J CO'Y!!A I"'LATE 14,!.' 1 &ILO r::\ X.211,8&&.I8 ='IÆ RACK ~ Y.2,362,124b;t. ",",0..... 'II'I!& I"'ETEIIiI ~ .,' ~DG.. :;i 5<.ø' .'. ~r.RL, OJ.l.PfI"'E!:!~I2Ð"><"!UZ:I' ~ATER ~moL. ) 1!!I eLDG. "'-DC>. I vAl'Æ WI. Þ 15'>0.5' .3 7~ f- GtUAIiD ~ PlI"'E -í.4'Xð.Ð' ~ --- UTIL TlTT 0.;.--- ~DG.. KU. 14-& IÐ' llLELl ~ X.nt.ø'1624 "".2,362.]060.56 ~ I X + \ I -~1e-IEAD F?E ~$ 3Ø'XS.ø' HEr AL COYER f'L.ATE c;mce &Hopoo/ E!lDG. ' .. ~ '" . , '62'· TELE~ c:A!SLE ~ 1UTJ.4~~'~P"'IfII'E 6.2'><6.1' . \"-. \ ) , N 8911'3&· W ~3' ":-~Œ CEN't ALJIt VENT eLOIU DCUN 3o'lCN!o.Ð'><!:o,Ø cc:NQr/:ETE PAD. , .J/ ~ pÄDFÕOTFR7, 2' ALCAP X·212)1'~ Y.2,»2,2Ø'1..1M 12's'X3ø ~~~T PACS R TOP. E~ pAQ ( ) SCALE: .. ~ : 2 z V4 = 6 X.21~.2h'3.602 , Y.¡"'2,D36-.13 ~ 1" 100' I. ELEvATION5 AT TI-4E TOP OF PIFES FOR MONITORING. WELL5 TAKEN wlm COVER OFF OR OPEN. 2. REFERENCE DATUM 15 MEAN SEA LEVEL = ø.øø' FOR ELEVATIONS 5J-KJU.N. 3. ALL BEARING.5 ARE GRID UNLESS NOTED OTI-4ERWISE 4. BASIS OF COORDINATES IS U.S.C. « G.S. TRI STATION AUDRY IN A.S.F. ZONE 4. (NAP 21) AVERAGE CONVEF<GENCE OF POINTS 5!-IOUN, ØI'So'So8" So. AUDRY L=ATlON, LAT, &Ø·3Ø'SoØ.50So~"N LONG, ISoI'I&'3 X = 2&~.86&.1So Y . 2.382.ø4So.42 tþ o ~ --{) :¢: @ @ [X] -0 ~ ~ NOTES LM MONUMENT FOUND TI-4IS SURVEY v," REBAR FOUND 2 v," BRASS CAP MONUMENT POWER POLE L IGI-4T POLE EXISTING. WELL CI-4RISTMAS TREE MONITOR WELL VALVE PIPING CONTINUES UNDERGROUND ELECTRICAL JUNCTION BOX SEPT IC VENT FOUND '" '" '" '" '" " « « z ~ o a .J o <0 <II '" .- X o [J] o a. EDGE PAD FOOTF'li!/NT ---------- iò,.=, __\ PIT I + ~ " " " .ø· ~D~~~DG. D T '". 'PIFE vAlY!:1iV 3.')(3..' ~ DIfI'E (!) £j K.DlJ.' 1 ).4".' 'SILO I8Ð'XI8.ø' TJ.ØIiEE ~"'Æ X.21I.&4*.>4 T.2.3é2,462.~ 1I1ATEIO IlELL aRCAðINCl &IDED 0 D (!) K1I. 21-1 \tþ'1SJLO )(.1'1.'528.~ T.2.3fo2,4....Ð6 /Kß.IJ. 23-1 ./ Ñ 2362311.&3612> o E 21212>1<;\,19"'" 'AD E!...EVATION=Æ?;;h' M.5.L. + 14.3' KU. 14 x·'& ·8ILELL~ ; . )(.212.£162.&1 Y.2,362,411.46 RESERVE PIT 14J' ~ KßlJ. 23-6X IlELL >-IOIJ&E X-7"l2)2221> Y.Z,362.!31.41 KU. 13-6 163' u.elL ~ r;-. if¡ X.212.22ø.4.41 L:.J:t Y-2,362,416,36. 14.1' "Çl \4J' ~ ~ Kß.IJ. 24-& IlELL >-IOIJ&E X.Tl2)&2~ T -2,362,»4.Ð4 K 31-1X ~LL I-ICœE X·212,2"",$ T.2.362.3'3~ I l J ~ ~ x UELL "C" X.21ZþlØØ1 T.2.362þ~ TOP h· CA!oING EL.&2.13' GRiOI..I'Ð EL.6L&' TOP 2" P!FE EL.-h2.w.' . + UELL "A" ~:;;'~~:i5ó e TOP" h" FtÆ EL..h2b2' ~EL·&l5'· ~ I TOE I'<ESERYE e e e IlELL"e. x.212.ø61.&'1 Y.Z,362,1æ.'!I6> TOP 6" CA&FNG EL.&IB4' ~EL."".ð' e .... '1--' '1.>.J- ....J. .Z. .~. ·0· ·0· c.,). 3 . Y· . . .0 <. ·0 "'. J:' '~.j '~'. >-'. ':.::. .(1) Z· .", O· ..... ::::;. '<. .:.:: LEGEND 8 7 12 ILocation 14-06 VICINITY MAP NOT TO SCALE 7 9 16 CI.. :3 ~ \J- \JI \JI .!:: c +-> :e ~ ~I- c ':> \J >~ Z~ <tOP A.C> :E<t~ OA.~ CJC; ......~ -W..l OiLS III Z U) I 0<t~ %C)a ~-<C =<ta. <tZ :E~ ~. Lt1 '" " '" '" <II " t"- O '" X « "- <II " .- '" <II " t"- O '" .J ~ t- ~ IÕ ~ :;¿ ~ ~ ¡¡: !5 I!:! < o ... 0<) 1 Õ Ó z ~ o ŒI 9 '" ¡¡: "' '" ;;; õ ó z ~ ::E::E2 ~55 ..,.fI?N_ I!:! < o > '" '" ~ >= a. 5 fJ '" o 8 tit - r 31 32 33 34 T5N _ KENAIJ - ~f T4N GAS FIELD a: a: 5 4 >- m ...."""'11 ,'~OF~', :- t' I, [!49D1* *"~ :: :: 'Í \ M. SCOTT 1Id..ANE'I : t" "4e28-S : 1".'-rS$iCJWol.--'.........-- ,."""" w ~ --1 Z o I- l) W <J) 1 fó 12 1 X=2112>,SI2>8.312> .,..=2,3fó2ß1I2>ßI e e . ß~ "ç::: N 23fó2311.æfól2> ,.,. E 21212>1S.lSSI2> 8 m ..., LATITUDE, fól2>'21'312512>"N LONC¡TUDE, 151·15'4fó.SI8"W SEC. IÓ T 4N RIIW SM AK 1112>5' FWL PAD ~-fó @ ELEVA¡ION=fó5_fó' H_5.L. @ o --' (/) 1L SECTION LINE + SEC. 1 T 4N RIIW SM AK ~~&~~Øi.3~~:elu9a E 2128412>.1112>12> IS85' FWL 2141' FNL K6.U. 23-1 TD N 2358812>5.812>12>12> E 212Sfó1.112>12>12> 2122' FWL 3235' FNL Consulting c;- roup Testing ~ SURFACE LOCATION DIAGRAM DAiE Of SURVEY: 11 .... BOOK NO.: 03309. DRAWING NO.: 033095 '.-200' DRAWN BY: WSW ENGINEER APPROVAL BY DA PRO.£CT STRUCT. PROCESS MCHAN. ElECT. INSlRUU. ARCH. No. DATE BY APP. """5IONS (Nt) Marathon WARATHON Oil Company . Alaska Region KENAI GAS FIELD PAD 14-6 KENAI, ALASKA KBU 23-7 SURFACE LOCATION SCALE DWN._ CHI<D. '--1 APP. APP DAiE t1/t7¡b.1 DAlE DAlE R£V Fll,£ NO. Marathon Oil \Ven: KBU23-7 Kenai Gas Pad 41-7 Ii III ,.1110"'" e ¡--- Ce.,!.' by bm;çhoe' .----- o 400 800 1200 1600 2000 2400 ,.-.., -- 2800 Q) Q) '+- '--' 3200 ..c -- 0... Q) 0 3600 0 0 4000 -- L Q) > 4400 Q) :::J L I- 4800 I V 5200 5600 6000 6400 6800 7200 7600 8000 400 e MARATHON Oil Company Structure: Pad 14-6 Well : KBU23-7 , Location: Kenai Peninsula, Alaska I Field : Kenai Gas Field 20 Conductor 0.00 2.00 4.00 5.00 4.00 2.00 0.00 0,00 Nudge 2/100 End Nudge Drop 2/100 EOD 13 3/8 KOP Casing Dote plotted: 18-Nov-2003 Plot Reference is KBU 23-7 Version#1. iCoordinotes ore in feet reference slot #KBU 23-7. Vertical Depths ore reference RKB (Glocìer#1 ).: r~iI. BAKER HUGHES INTEQ j l 0.00 3.00 6.00 9.00 12.00 15.00 18.00 21.00 24.00 27.00 30.00 33.00 39.00 45.00 50.45 OLS: 3.00 deg per 100 It EOC Drop 50.45 47.08 44.08 41.08 38,08 35.08 9 5/8 Casing 33.58 32.08 Target- T /Mid Beluga OLS: 1.50 deg per 100 It DLS: 1,50 deg per 100 ft 28.50 27.00 25,50 24.00 22.50 21.00 19.50 18.00 16.50 15.00 13.50 12.00 10.50 9.00 7.50 6.00 4.50 3.00 1.50 EOD 0.00 TO - Csg pt. 3 1/2 o 400 800 1200 1600 2000 2400 2800 3200 Vertical Section (feet) -> Azimuth 163.93 with reference 0.00 N, 0.00 W from slot #KBU 23-7 East (feet) -> o 800 400 1200 400 Casing o 400 800 tf) 1200 0 C -- :::r 1600 ,.-.., -+. (I) (I) -- 2000 '--' I V 2400 2800 9 5/8 Target- T /Mid 3200 TO - Csg pt. 3 1/2 3600 WELL PROFILE DATA ----I /, ----- P.>inL _un [)e.;¡/IQOI End 01 DropjTurn TorgeIK8U2J7-r/I,hd TD"Torg&l 9113,5,3 3600 4000 e e MARATHON Oil Company Pad 14-6 KBU23-7 slot #KBU 23-7 Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU 23-7 Version#l prop5567 Date printed Date created Last revised 18-Nov-2003 6-Nov-2003 18-Nov-2003 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on n60 27 33.151,w151 16 7.223 Slot location is n60 27 37.250,w151 15 46.918 Slot Grid coordinates are N 2362371.636, E 272019.199 Slot local coordinates are 416.30 N 1018.22 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 750.00 850.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3181.66 3500.00 4000.00 4500.00 5000.00 5275.07 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 0.00 0.00 0.00 0.00 0.00 0.00 64.00 64.00 64.00 64.00 0.00 100.00 200.00 300.00 400.00 500.00 599.98 699.84 749.68 849.30 899.15 999.01 1098.99 1198.99 1298.99 1398.99 1498.99 1598.94 1698.62 1797.75 1896.07 1993.29 2089.16 2183.42 2275.79 2366.04 2453.91 2539.17 2621. 57 2700.90 2776.93 2849.46 2918.29 2971. 61 3174.32 3492.70 3811.07 4129.45 4304.60 4320.54 4385.71 4452.85 4521.90 4592.83 4665.57 4740.09 4816.32 4894.22 4973.74 5054.82 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.77 N 3.06 N 4.78 N 8.60 N 10.32 N 12.61 N 13.38 N 13.38 N 13.38 N 13.38 N 13.38 N 10.86 N 3.30 N 9.28 S 26.83 S 49.32 S 76.68 S 108.84 S 145.71 S 187.18 S 233.15 S 283.48 S 338.05 S 396.70 S 459.26 S 525.58 S 595.46 S 655.03 S 891.53 S 1262.98 S 1634.43 S 2005.89 S 2210.24 S 2228.71 S 2301.78 S 2373.18 S 2442.86 S 2510.78 S 2576.89 S 2641.14 S 2703.49 S 2763.89 S 2822.31 S 2878.70 S 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 1.57 E 6.27 E 9.80 E 17 . 63 E 21.16 E 25.86 E 27.43 E 27.43 E 27 . 43 E 27.43 E 27.43 E 28.13 E 30.23 E 33.73 E 38.61 E 44.86 E 52.46 E 61.40 E 71. 65 E 83.17 E 95.95 E 109.94 E 125.11 E 141.41 E 158.80 E 177.23 E 196.65 E 213.21 E 278.94 E 382.19 E 485.43 E 588.67 E 645.47 E 650.60 E 670.91 E 690.76 E 710.13 E 729.00 E 747.38 E 765.24 E 782.57 E 799.36 E 815.60 B 831. 27 B Dogleg Deg/100ft e PROPOSAL LISTING Page 1 Your ref KBU 23-7 Version#l Last revised : 18-Nov-2003 Vert Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 4.00 5.00 5.00 64.00 64.00 64.00 64.00 64.00 0.00 2.00 2.00 2.00 0.00 0.00 Nudge 2/100 -0.30 -1. 20 -1.88 End Nudge -3.38 Drop 2/100 4.00 2.00 0.00 0.00 0.00 64.00 64.00 164.45 164.47 164.47 2.00 2.00 2.00 0.00 0.00 -4.06 -4.96 -5.26 EOD -5.26 -5.26 0.00 0.00 3.00 6.00 9.00 164.47 164.47 164.47 164.47 164.47 0.00 0.00 3.00 3.00 3.00 -5.26 13 3/8" Casing -5.26 KOP -2.64 5.20 18.25 12.00 15.00 18.00 21.00 24.00 164.47 164.47 164.47 164.47 164.47 3.00 3.00 3.00 3.00 3.00 36.47 59.81 88.21 121. 59 159.85 27.00 30.00 33.00 36.00 39.00 164.47 164.47 164.47 164.47 164.47 3.00 3.00 3.00 3.00 3.00 202.89 250.60 302.84 359.47 420.34 42.00 45.00 48.00 50.45 50.45 164.47 164.47 164.47 164.47 164.47 3.00 3.00 3.00 3.00 0.00 485.27 554.10 626.63 688.46 BOC 933.91 50.45 50.45 50.45 50.45 50.08 164.47 164.47 164.47 164.47 164.47 0.00 0.00 0.00 0.00 1. 50 1319.42 1704.94 2090.46 2302.54 Begin Drop 2321.71 48.58 47.08 45.58 44.08 42.58 164.47 164.47 164.47 164.47 164.47 1.50 1. 50 1. 50 1.50 1. 50 2397.55 2471.66 2543.98 2614.47 2683.08 41.08 39.58 38.08 36.58 35.08 164.47 164.47 164.47 164.47 164.47 1. 50 1. 50 1.50 1.50 1.50 2749.76 2814.47 2877.16 2937.79 2996.32 All data is in feet unless otherwise stated. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level; Bottom hole distance is 3689.98 on azimuth 164.00 degrees from wellhead. Total Dogleg for wellpath is 110.90 degrees. vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company PROPOSAL LISTING Page 2 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 18-Nov-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 6400.00 33.58 164.47 5137.40 2933.03 S 846.37 E 1. 50 3052.71 6500.00 32.08 164.47 5221.43 2985.26 S 860.89 E 1. 50 3106.91 6588.39 30.75 164.47 5296.86 3029.64 S 873.23 E 1. 50 3152.98 9 5/8" Casing 6600.00 30.58 164.47 5306.85 3035.35 S 874.81 E 1. 50 3158.90 6638.39 30.00 164.47 5340.00 3054.00 S 880.00 E 1.50 3178.26 KBU237 - T/Mid Beluga Rvsd 11/17/03 6738.39 28.50 164.47 5427.25 3101. 08 S 893.09 E 1. 50 3227.12 6838.39 27.00 164.47 5515.74 3145.93 S 905.56 E 1. 50 3273.67 6938.39 25.50 164.47 5605.43 3188.55 S 917.40 E 1. 50 3317.90 7038.39 24.00 164.47 5696.24 3228.88 S 928.61 E 1. 50 3359.76 7138.39 22.50 164.47 5788.12 3266.91 S 939.19 E 1. 50 3399.23 7238.39 21.00 164.47 5880.99 3302.61 S 949.11 E 1.50 3436.29 7338.39 19.50 164.47 5974.81 3335.96 S 958.38 E 1.50 3470.90 7438.39 18.00 164.47 6069.50 3366.93 S 966.99 E 1.50 3503.04 7538.39 16.50 164.47 6165.00 3395.50 S 974.93 E 1. 50 3532.69 7638.39 15.00 164.47 6261. 24 3421.65 S 982.20 E 1. 50 3559.83 7738.39 13.50 164.47 6358.16 3445.37 S 988.79 E 1. 50 3584.44 7838.39 12.00 164.47 6455.70 3466.63 S 994.70 E 1. 50 3606.51 7938.39 10.50 164.47 6553.77 3485.42 S 999.93 E 1. 50 3626.02 8038.39 9.00 164.47 6652.32 3501.74 S 1004.46 E 1.50 3642.95 8138.39 7.50 164.47 6751.29 3515.57 S 1008.31 E 1.50 3657.30 8238.39 6.00 164.47 6850.59 3526.89 S 1011.45 E 1. 50 3669.06 8338.39 4.50 164.47 6950.17 3535.70 S 1013.91 E 1. 50 3678.20 8438.39 3.00 164.47 7049.95 3542.01 S 1015.66 E 1. 50 3684.74 8538.39 1. 50 164.47 7149.87 3545.79 S 1016.71 E 1. 50 3688.67 8638.39 0.00 164.47 7249.86 3547.05 S 1017.06 E 1. 50 3689.98 EOD 9000.00 0.00 164.47 7611.47 3547.05 S 1017.06 E 0.00 3689.98 9113.53 0.00 164.47 7725.00 3547.05 S 1017.06 E 0.00 3689.98 TD - Csg pt. All data is in feet unless otherwise stated. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Bottom hole distance is 3689.98 on azimuth 164.00 degrees from wellhead. Total Dogleg for wellpath is 110.90 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref KBU 23-7 Version#l Last revised : 18-Nov-2003 Comments in wellpath ------~-----~------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 500.00 500.00 0.00 N 0.00 W Nudge 2/100 750.00 749.68 4.78 N 9.80 E End Nudge 850.00 849.30 8.60 N 17.63 E Drop 2/100 1100.00 1098.99 13.38 N 27.43 E EOD 1400.00 1398.99 13.38 N 27.43 E 13 3/8" Casing 1500.00 1498.99 13.38 N 27.43 E KOP 3181.66 2971.61 655.03 S 213.21 E EOC 5275.07 4304.60 2210.24 S 645.47 E Begin Drop 6588.39 5296.86 3029.64 5 873.23 E 9 5/8" Casing 6638.39 5340.00 3054.00 5 880.00 E KBU237 - T/Mid Beluga Rvsd 11/17/03 8638.39 7249.86 3547.05 5 1017.06 E EOD ¡ 9113.53 7725.00 3547.05 5 1017.06 E TD - Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD 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 O.OON O.OON O.OON O.OON O.oow O.OOW O.OOW O.OOW 100.00 1400.00 6588.39 9113.53 100.00 1398.99 5296.86 7725.00 O.OON 13 . 38N 3029.645 3547.055 O.OOW 27.43E 873.23E 1017.06E 20" Conductor 13 3/8" 9 5/8" 3 1/2" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KBU237 - TD Tgt - Rv KBU237 - T/Mid Belug 7725.00 5340.00 3547.055 3054.005 1017.06E 880.00E 6-Nov-2003 6-Nov-2003 e e MARATHON Oil Company Pad 14-6 KBU23-7 slot #KBU 23-7 Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU 23-7 Version#l prop5567 Date printed Date created Last revised l8-Nov-2003 6-Nov-2003 l8-Nov-2003 Field is centred on 2709l6.030,2362063.980,999.00000,N Structure is centred on n60 27 33.l5l,w15l 16 7.223 Slot location is n60 27 37.250,w15l 15 46.918 Slot Grid coordinates are N 2362371.636, E 272019.199 Slot local coordinates are 416.30 N 1018.22 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 750.00 850.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 12.00 15.00 18.00 21. 00 24.00 2400.00 2500.00 2600.00 2700.00 2800.00 27.00 30.00 33.00 36.00 39.00 2900.00 3000.00 3100.00 3181.66 3500.00 42.00 45.00 48.00 50.45 50.45 4000.00 4500.00 5000.00 5275.07 5300.00 50.45 50.45 50.45 50.45 50.08 5400.00 5500.00 5600.00 5700.00 5800.00 48.58 47.08 45.58 44.08 42.58 5900.00 6000.00 6100.00 6200.00 6300.00 41.08 39.58 38.08 36.58 35.08 Azimuth Degrees 0.00 0.00 0.00 0.00 0.00 0.00 64.00 64.00 64.00 64.00 True Vert Depth 0.00 100.00 200.00 300.00 400.00 500.00 599.98 699.84 749.68 849.30 899.15 999.01 1098.99 1198.99 1298.99 1398.99 1498.99 1598.94 1698.62 1797.75 1896.07 1993.29 2089.16 2183.42 2275.79 2366.04 2453.91 2539.17 2621.57 2700.90 2776.93 2849.46 2918.29 2971.61 3174.32 3492.70 3811. 07 4129.45 4304.60 4320.54 4385.71 4452.85 4521.90 4592.83 4665.57 4740.09 4816.32 4894.22 4973.74 5054.82 e PROPOSAL LISTING Page 1 Your ref KBU 23-7 Version#l Last revised : 18-Nov-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/100ft Sect O.OON O.OON O.OON O.OON O.OON O.OON 0.77N 3.06N 4.78N 8.60N 10.32N 12.61N 13.38N 13.38N 13.38N 13.38N 13.38N 10.86N 3.30N 9.28S 26.83S 49.32S 76.68S 108.84S 145.71S 187.18S 233.15S 283.48S 338.05S 396.70S 459.26S 525.58S 595.46S 655.03S 891. 53S 1262.98S 1634.43S 2005.89S 2210.24S 2228.71S 2301. 78S 2373.18S 2442.86S 2510.78S 2576.89S 2641.14S 2703.49S 2763.89S 2822.31S 2878.70S O.oow O.OOW O.OOW O.OOW O.OOW O.OOW 1. 57E 6.27E 9.80E 17.63E 21. 16E 25.86E 27 . 43E 27.43E 27.43E 27.43E 27.43E 28.13E 30.23E 33.73E 38.61E 44.86E 52.46E 61.40E 71.65E 83.17E 95.95E 109.94E 125.UE 141.41E 158.80E 177.23E 196.65E 213.21E 278.94E 382.19E 485.43E 588.67E 645.47E 650.60E 670.91E 690.76E 710.13E 729.00E 747.38E 765.24E 782.57E 799.36E 815.60E 831.27E 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 0.00 0.00 -0.30 -1. 20 -1. 88 -3.38 G RID Easting 0.00 0.00 0.00 0.00 0.00 272019.20 272019.20 272019.20 272019.20 272019.20 COORDS Northing 2362371.64 2362371. 64 2362371.64 2362371.64 2362371.64 2362371.64 2362372 .37 2362374.57 2362376.22 2362379.89 2362381.54 2362383.75 2362384.48 2362384.48 2362384.48 2362384.48 2362384.48 2362381.95 2362374.35 2362361. 71 2362344.07 2362321.46 2362293.96 2362261.64 2362224.58 2362182.89 2362136.69 2362086.10 2362031.25 2361972.30 2361909.42 2361842.76 2361772.53 2361712.64 2361474.93 2361101.58 2360728.22 2360354.86 2360149.47 2360130.90 2360057.45 2359985.68 2359915.64 2359847.38 2359780.93 2359716.35 2359653.68 2359592.97 2359534.25 2359477.57 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level) . Bottom hole distance is 3689.98 on azimuth 164.00 degrees from wellhead. Total Dogleg for wellpath is 110.90 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.00 2.00 4.00 5.00 5.00 64.00 64.00 64.00 64.00 64.00 4.00 2.00 0.00 0.00 0.00 64.00 64.00 164.45 164.47 164.47 0.00 0.00 3.00 6.00 9.00 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 164.47 2.00 2.00 2.00 0.00 0.00 -4.06 -4.96 -5.26 -5.26 -5.26 0.00 0.00 3.00 3.00 3.00 -5.26 -5.26 -2.64 5.20 18.25 3.00 3.00 3.00 3.00 3.00 36.47 59.81 88.21 121.59 159.85 3.00 3.00 3.00 3.00 3.00 202.89 250.60 302.84 359.47 420.34 3.00 3.00 3.00 3.00 0.00 485.27 554.10 626.63 688.46 933.91 0.00 0.00 0.00 0.00 1. 50 1319.42 1704.94 2090.46 2302.54 2321. 71 1. 50 1. 50 1. 50 1. 50 1. 50 2397.55 2471.66 2543.98 2614.47 2683.08 1. 50 1. 50 1. 50 1. 50 1. 50 2749.76 2814.47 2877.16 2937.79 2996.32 272019.20 272020.78 272025.53 272029.09 272036.99 272040.55 272045.30 272046.88 272046.88 272046.88 272046.88 272046.88 272047.53 272049.49 272052.74 272057.28 272063.10 272070.17 272078.49 272088.02 272098.75 272110.64 272123.65 272137.77 272152.93 272169.11 272186.26 272204.34 272219.74 272280.91 272376.97 272473.03 272569.10 272621.95 272626.72 272645.62 272664.09 272682.11 272699.67 272716.77 272733.39 272749.51 272765.14 272780.25 272794.83 e e MARATHON Oil Company PROP05AL LI5TING Page 2 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised 18-Nov-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 5 Depth Degrees Degrees Depth C 0 0 R D I N A T E 5 Deg/lOOft Sect Easting Northing 6400.00 33.58 164.47 5137.40 2933.035 846.37E 1. 50 3052.71 272808.88 2359422.96 6500.00 32.08 164.47 5221.43 2985.265 860.89E 1. 50 3106.91 272822.39 2359370.47 6588.39 30.75 164.47 5296.86 3029.645 873.23E 1. 50 3152.98 272833.87 2359325.86 6600.00 30.58 164.47 5306.85 3035.355 874.81E 1. 50 3158.90 272835.35 2359320.12 6638.39 30.00 164.47 5340.00 3054.005 880.00E 1. 50 3178.26 272840.17 2359301.37 6738.39 28.50 164.47 5427.25 3101.085 893.09E 1. 50 3227.12 272852.35 2359254.06 6838.39 27.00 164.47 5515.74 3145.935 905.56E 1. 50 3273.67 272863.95 2359208.97 6938.39 25.50 164.47 5605.43 3188.555 917.40E 1. 50 3317 . 90 272874.97 2359166.14 7038.39 24.00 164.47 5696.24 3228.885 928.61E 1. 50 3359.76 272885.41 2359125.60 7138.39 22.50 164.47 5788.12 3266.915 939.19E 1. 50 3399.23 272895.24 2359087.37 7238.39 21.00 164.47 5880.99 3302.615 949.11E 1.50 3436.29 272904.48 2359051.48 7338.39 19.50 164.47 5974.81 3335.965 958.38E 1. 50 3470.90 272913.10 2359017.97 7438.39 18.00 164.47 6069.50 3366.935 966.99E 1. 50 3503.04 272921.11 2358986.84 7538.39 16.50 164.47 6165.00 3395.505 974.93E 1. 50 3532.69 272928.50 2358958.12 7638.39 15.00 164.47 6261. 24 3421.655 982.20E 1. 50 3559.83 272935.27 2358931.84 7738.39 13.50 164.47 6358.16 3445.375 988.79E 1. 50 3584.44 272941.40 2358908.00 7838.39 12.00 164.47 6455.70 3466.635 994.70E 1. 50 3606.51 272946.90 2358886.63 7938.39 10.50 164.47 6553.77 3485.425 999.93E 1. 50 3626.02 272951. 76 2358867.74 8038.39 9.00 164.47 6652.32 3501. 745 1004.46E 1. 50 3642.95 272955.98 2358851.34 8138.39 7.50 164.47 6751.29 3515.575 1008.31E 1. 50 3657.30 272959.56 2358837.44 8238.39 6.00 164.47 6850.59 3526.895 1011.45E 1. 50 3669.06 272962.49 2358826.06 8338.39 4.50 164.47 6950.17 3535.705 1013.91E 1.50 3678.20 272964.77 2358817.20 8438.39 3.00 164.47 7049.95 3542.015 1015.66E 1. 50 3684.74 272966.40 2358810.87 8538.39 1. 50 164.47 7149.87 3545.795 1016.71E 1. 50 3688.67 272967.38 2358807.06 8638.39 0.00 164.47 7249.86 3547.055 1017.06E 1. 50 3689.98 272967.70 2358805.80 9000.00 0.00 164.47 7611.47 3547.055 1017.06E 0.00 3689.98 272967.70 2358805.80 9113.53 0.00 164.47 7725.00 3547.055 1017.06E 0.00 3689.98 272967.70 2358805.80 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Bottom hole distance is 3689.98 on azimuth 164.00 degrees from wellhead. Total Dogleg for wellpath is 110.90 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e e MARATHON Oil Company Pad l4-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska PROP05AL LI5TING Page 3 Your ref KBU 23-7 Version#l Last revised : 18-Nov-2003 Comments in wellpath ----~-~------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 500.00 500.00 O.OON O.OON Nudge 2/100 750.00 749.68 4.78N 9.80E End Nudge 850.00 849.30 8.60N 17.63E Drop 2/100 1100.00 1098.99 13.38N 27.43E EOD 1400.00 1398.99 13.38N 27 . 43E 13 3/8" Casing 1500.00 1498.99 13.38N 27.43E KOP 3181.66 2971.61 655.035 213.21E EOC 5275.07 4304.60 2210.245 645.47E Begin Drop 6588.39 5296.86 3029.645 873.23E 9 5/8" Casing 6638.39 5340.00 3054.005 880.00E KBU237 - T/Mid Beluga Rvsd 11/17/03 8638.39 7249.86 3547.055 1017.06E EOD 9113.53 7725.00 3547.055 1017.06E TD - Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD 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 O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON 100.00 1400.00 6588.39 9113.53 100.00 1398.99 5296.86 7725.00 O.OON 13.38N 3029.645 3547.055 O.OON 27.43E 873.23E 1017.06E 2011 Conductor 13 3/8" 9 5/8" 3 1/2" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KBU237 - TD Tgt - Rv KBU237 - T/Mid Belug 7725.00 5340.00 3547.055 3054.005 1017.06E 880.00E 6-Nov-2003 6-Nov-2003 Creoied by bm;çhoe! om Structure : Pad 14-6 Well: KBU23-7 Field ; Kenai Gas Field Location: Kenai Peninsula, Alaska U NO H 260 , '--' 2400 o 320 o 280 270 100 250 1 1 0 40 120 30 130 20 210 2 160 190 180 o NOI~mol Pion Iling I' I !I oer - e All de s shown ore Measured on Reference piotted 17 -Nov-2003 il om a Plot Reference is KBU 23-7 Versior,#1 #K8U RK6 Structure: Pad 14-6 Well : KBU23-7 Field: Kenai Gas Fjeld Location : Keno! Peninsula, Alaska East (feet) -> 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 600 100 1700 ~ 00 3900 800 800 \ 00 \ 4300 \ 4300 1000 1000 , 3300 4500 \ 1200 \ \ 3500 \ 1400 \ \ \ 3700 1600 \ \ \ 1600 0\ \ \ 2000 ,4100 \ \ ~ 2200 \ 4300 U) -- 0 Q) Q) \ !C '+- \ -+- '-../ ;:y 2400 \ 4500 ...!C ~ -- \ 5700 -. ::; \ (IJ 2600 '\ 4700 2600 (IJ -+- 6100 '-../ I \ I ~ 4900 \I 2800 2800 \I 3000 3000 3200 3200 5900 3400 "'..> 6700 3400 °0 6500 ) 6300 3600 \ 3600 5100 3800 ~ 5900 3800 5700 4000 5500 4000 5300 4200 5100 4200 4400 4400 600 400 200 0 200 400 600 300 1000 1200 1400 1600 1600 2000 22 DO 2400 2600 East ( -> Date piotted P ·Nov·-2003 Jil om a Structure : Pod 14-6 Well: KBU23-7 ----~ Field : Kenai Gas Field Location: Kenai Península, Aiaska INTEQ East -> 240 200 160 120 80 40 40 80 360 4DO 500 40 1100 1900 0 EJ300 0 1 1900 41 40 / /0'-> 21 40 / So 00 1700 0 80 2100\ 80 \ 1900 \ " 20 \ 2100 120 \ \ 160 , 2300 160 \ 2500 \ 200 \ 200 700 \ \ 240 \ 240 r--.. \ 2500 00 (j) - (]) 900 0 (]) 280 \ 280 C "- \ -+ "-../ ::Y \ ...c \ ~ - 320 320 :J \ 0 \ V1 1100 \ 360 360 I \ \j \ \ I \ 400 \ 2700 400 \ \ 440 \ 440 \ \ 480 \ 480 \ \ 520 \ 520 \ \ 560 \ \ , 2900 \ 600 \ 600 \ \ 640 \ 640 680 660 240 200 160 í20 80 40 0 40 80 120 150 200 260 320 360 400 a (feet) -> e MARATHON Oil Company Pad 14-6 KBU23-7 slot #KBU 23-7 Kenai Gas Field Kenai Peninsula, Alaska e 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 KBU 23-7 Version#l prop5567 Date printed Date created Last revised 17-Nov-2003 6-Nov-2003 17-Nov-2003 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on n60 27 33.151,w151 16 7.223 Slot location is n60 27 37.250,w151 15 46.918 Slot Grid coordinates are N 2362371.636, E 272019.199 Slot local coordinates are 416.30 N 1018.22 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Object we11path DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* KBU33-6X Version 2"KBU33-6X,Pad 41-7 MWD <0-5300>"KBU41-7X,Pad 41-7 KBU43-7X Ver 3"KBU43-7X,Pad 41-7 MWD <0-8610>"KBU43-7X,Pad 41-7 GMS <0-7290>"KBU41-7,Pad 41-7 MWD <0-7440>"KBU 44-6,Pad 41-7 MWD <3470 - 4816>"KU24-5Rd,Pad 41-7 MSS <4320 - 10810'>"KDU4Rd,pad 41-7 GMS <0-5549'>"KDU4,Pad 41-7 MSS <0-5707'>"KU 43-7,Pad 41-7 PMSS <0 - 7570>"KBU42-7,Pad 41-7 GMS <0-5350'>"KUll-8,Pad 41-7 GMS <0-5900'>"KU24-5,Pad 41-7 PMSS <8846 - 10960>"KTU24-6H,Pad 41-7 GMS <0-7902'>"KBU33-6,Pad 41-7 GMS <0-8120'>"KU13-5,Pad 41-7 MSS <0-10522'>"KDU#2,Pad 41-7 MSS <0-5300'>,,43-6A,Pad 41-7 PMSS <0-8864>"KTU32-7,Pad 41-7 KTU43-6XRd Ver.7,,43-6X Rd,Pad 41-7 PGMS <0-8370'>,,43-6,Pad 41-7 PMSS <7670-9464'>,,43-6X Rd,pad 41-7 MWD <4250 - 5740>"KU43-6RD,pad 41-7 MSS <4305 - 5701>"KU43-6,Pad 41-7 MWD <0 - 11857'>"KTU32-7H,Pad 41-7 GMS <0-11095'>"KDU6,Pad #? Minimum Distance method M.D. Diverging from M.D. 3220.0 3220.0 4320.0 4320.0 8720.0 8720.0 8820.0 8820.0 4040.0 8660.0 3300.0 8700.0 0.0 862.5 8860.0 8860.0 5842.9 5842.9 6709.8 6709.8 950.0 8700.0 400.0 2933.3 0.0 862.5 3800.0 3800.0 2677.8 2677.8 937.5 937.5 300.0 3077.8 200.0 925.0 8181.2 9113.5 9113.5 9113.5 3077.8 3077.8 3077.8 3077.8 2544.4 2777.8 2544.4 2777.8 9113.5 9113.5 700.0 950.0 Closest approach with 3-D Last revised Distance 3-0ct-2003 19-Mar-2002 6-Jun-2003 13-Jun-2003 13-Mar-2002 3-Mar-2002 9-Jan-2002 5-May-1995 5-May-1995 2l-Jan-1994 9-Feb-2001 21-Jan-1994 2l-Jan-1994 1-Aug-2000 22-Jun-2000 2l-Jan-1994 21-Jan-1994 20-Jan-1994 31-Aug-2000 20-Apr-1999 23-Jul-1995 16-Aug-1995 30-Jan-2002 31-Jan-2002 17-May-2002 30-May-1995 2764.1 2590.7 1459.6 1453.6 2892.8 3084.6 3300.2 622.2 891. 3 2341. 6 3013.9 3240.9 3300.3 2786.9 27 32.6 3100.8 3245.7 3245.3 1779.3 6095.3 2776.1 2776.1 2903.0 2903.0 2065.8 5939.6 e e PGMS <0-5700'>"KU14-32,Pad #? 30-May-1995 5834.2 400.0 700.0 GMS <0-10502'>"KDU5,Pad #? 30-May-1995 5665.1 1755.6 9113.5 Incl. only <0-5809'>"KU34-31,Pad #? 30-May-1995 5720.3 0.0 840.0 MSS <0-4459'>"KUll-6,Pad #? 30-May-1995 5000.7 2122.2 2122.2 PGMS <O-3300'>"WD-l,Pad #? 30-May-1995 5767.8 1522.2 1522.2 MWD <3452 - 5650'>"KU21-6X,Pad #? 18-0ct-2001 5066.5 1955.6 2033.3 MSS <0 - 5678'> Depth Shifted"KU21-6X,Pad #? 18-0ct-2001 5058.2 2011.1 2011.1 PGMS <77 8 - 5650>"KU21-6X,Pad #? 11-Jan-2002 5013 .1 1944.4 2155.6 GMS <0-5820'>"KU24-7,Pad #?? 31-May-1995 2223.4 6952.7 6952.7 MMS <0-7910'>"KBU33-7,Pad #?? 31-May-1995 616.4 8367.0 8367.0 KU14X-6RD Version #1"KU14X-6Rd,Pad 14-6 11-Dec-2002 403.8 2544.4 2544.4 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 1 11-Dec-2002 85.0 1511.1 1511.1 GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6, 11-Dec-2002 85.0 1511.1 1511.1 MSS <9776 - 10225>"KU14X-6,Pad 14-6 11-Dec-2002 84.9 1511.1 1511.1 GMS <0 - 9500>"KU14X-6,Pad 14-6 11-Dec-2002 84.9 1511.1 1511.1 INCLINATION ONLY"KU14-6,Pad 14-6 7-Nov-2003 156.9 512.5 9113.5 PMSS <O-???'>"KU 31-7,Pad 14-6 10-Jan-2001 220.7 0.0 760.0 MSS <0-6530'>"KU43-12,Pad 14-6 12-May-1995 197.5 0.0 0.0 MSS <0-9895'>"KDU-1,Pad 14-6 12-May-1995 204.3 500.0 1500.0 MSS <0-5500'>"KU13-6,Pad 14-6 12-May-1995 205.5 875.0 875.0 GMS <0-6950'>"KBU23X-6,Pad 14-6 12-May-1995 68.6 1611. 1 1611.1 WD-2 Version #1"WD-2,Pad 14-6 26-Mar-1999 232.0 500.0 1500.0 GMS <0-7375'>"KBU31-7,Pad 14-6 14-Sep-1995 183.9 1050.0 8052.7 PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 28-Sep-1995 183.9 1050.0 1050.0 PMSS <0 - ????>"KBU24-6,Pad 14-6 12-Mar-2001 101.1 1688.9 8660.0 MSS <0-4453'>"KU21-7,Pad 14-6 12-May-1995 50.5 1400.0 2177.8 e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T. V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861.8 874.2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911. 6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961. 5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011. 5 1024.0 1036.5 1049.0 1061. 5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O.ON O.ON O.ON O.ON O. ON O.ON O. ON O.ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N 1. ON 1.2N 1.4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11.7N 11. 9N 12.2N 12.4N 12.6N 12.8N 12.9N 13.1N 13.2N 13.3N 13.3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21.2E 21. 9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27.2E 27.3E 27.4E 27.4E 27.4E 27.4E 27.4E Object we11path O.ow O.OW o. OW O.OW O.OW 0.1 100.3 200.1 300.0 400.0 M.D. T. V.D. 0.1 100.3 200.1 300.0 400.0 500.0 512.5 525.0 537.7 550.2 562.7 575.2 587.7 600.2 612.7 625.2 637.7 650.2 662.6 675.1 687.7 700.2 712.6 725.1 737.6 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911. 9 924.4 936.9 949.3 961. 8 974.3 986.8 999.3 1011. 8 1024.3 1036.7 1049.2 1061. 7 1074.2 1086.7 1099.2 1199.2 1299.2 1399.4 e CLEARANCE LISTING Page 2 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 14-6 Rect Coordinates 100.2N 100.0N 99.7N 99.6N 99.7N 99.8N 99.8N 99.9N 99.9N 99.9N 99.9N 99.9N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.7N 99.7N 99.7N 99.7N 99.7N 99.6N 99.6N 99.5N 99.4N 99.4N 99.4N 99.4N 99.3N 99.3N 99.3N 99.3N 99.2N 99.2N 99.2N 99.1N 99.1N 99.1N 99.0N 99.0N 99.0N 99.0N 98.9N 98.9N 98.6N 98.3N 97.9N 41.9E 41.9E 42.0E 41.9E 41.6E 41.3E 41. 3E 41.2E 41. 2E 41.1E 41.1E 41.0E 41. OE 40.9E 40.9E 40.8E 40.8E 40.7E 40.6E 40.6E 40.5E 40.5E 40.4E 40.4E 40.3E 40.2E 40.0E 39.7E 39.7E 39.6E 39.5E 39.4E 39.4E 39.3E 39.2E 39.1E 39.1E 39.0E 38.9E 38.8E 38.8E 38.7E 38.7E 38.6E 38.6E 38.5E 38.5E 38.5E 38.5E 39.0E 39.8E Horiz Bearing 22.7 22.8 22.8 22.8 22.7 108.6 108.4* 108.2* 108.1* 108.1* Minim Dist TCyl Dist 108.6 108.4* 108.2* 108.1* 108.1* 108.0* 108.0* 107.9* 107.8* 107.7* 107.5* 107.2* 107.0* 106.6* 106.3* 105.9* 105.4* 105.0* 104.5* 103.9* 103.3* 102.7* 102.0* 101. 3* 100.6* 99.6* 96.5* 93.5* 92.8* 92 .1* 99.8* 96.7* 93.7* 92.9* 92.2* O.OW O.OE O.lE 0.2E 0.4E 500.0 512.5 525.0 537.7 550.2 22 .5 22.4 22.4 22.3 22.2 108.0* 108.0* 107.9* 107.8* 107.7* 91.5* 90.9* 90.3* 89.8* 89.4* 91.6* 91.0* 90.4* 89.9* 89.4* 0.6E 0.9E 1.2E 1. 6E 2.0E 562.7 575.2 587.7 600.2 612.7 22.1 22.0 21. 8 21. 7 21. 5 107.5* 107.2* 106.9* 106.6* 106.2* 88.9* 88.5* 88.1* 87.8* 87.5* 89.0* 88.5* 88.2* 87.8* 87.5* 2.5E 3.0E 3.5E 4.1E 4.8E 625.2 637.7 650.2 662.6 675.1 21. 3 21. 0 20.8 20.5 20.2 105.8* 105.4* 104.9* 104.4* 103.8* 87.2* 87.0* 86.8* 86.6* 86.5* 86.4* 86.3* 86.2* 86.0* 85.7* 85.4* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 5.5E 6.3E 7.1E 7.9E 8.8E 687.7 700.2 712.6 725.1 737.6 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911.9 924.4 936.9 949.3 961.8 974.3 986.8 999.3 1011.8 1024.3 1036.8 1049.3 1061.8 1074.2 1086.7 1099.2 1199.2 1299.2 1399.4 19.8 19.5 19.1 18.7 18.3 103.2* 102.5* 101. 9* 101.2* 100.4* 17.8 15.8 13.7 13.1 12.6 12.1 11.6 11.1 10.7 10.3 9.9 9.5 9.2 8.8 8.5 8.3 8.0 7.8 7.7 7.5 87.2* 87.0* 86.8* 86.6* 86.5* 7.4 7.4 7.4 7.4 7.8 86.4* 86.3* 86.2* 86.0* 85.7* 8.3 85.4* e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1500.0 1511.1 1522.2 1533.3 1544.4 1499.0 1510.1 1521.2 1532.3 1543.4 1555.6 1566.7 1577.8 1588.9 1600.0 1554.5 1565.6 1576.7 1587.8 1598.9 1611.1 1622.2 1633.3 1644.4 1655.6 1610.0 1621.1 1632.2 1643.3 1654.4 1666.7 1677.8 1688.9 1700.0 1711.1 1665.4 1676.5 1687.6 1698.6 1709.7 1722.2 1733.3 1744.4 17 55.6 1766.7 1720.7 1731.7 1742.8 1753.8 1764.8 1777.8 1788.9 1800.0 1811.1 1822.2 1775.8 1786.8 1797.8 1808.7 1819.7 1833.3 1844.4 1855.6 1866.7 1877.8 1830.6 1841. 6 1852.5 1863.4 1874.3 1888.9 1900.0 1911.1 1922.2 1933.3 1885.2 1896 .1 1906.9 1917.8 1928.6 1944.4 1955.6 1966.7 1977.8 1988.9 1939.4 1950.2 1961.0 1971. 8 1982.6 2000.0 2011.1 2022.2 2033.3 2044.4 1993.3 2004.0 2014.7 2025.4 2036.1 2055.6 2046.7 13.4N 13.3N 13.3N 13.1N 12.9N 12.6N 12.3N 11.9N 11. 4N 10.9N 10.3N 9.6N 8.9N 8.1N 7.3N 6.4N 5.4N 4.4N 3.3N 2.1N 0.9N 0.38 1. 78 3.18 4.58 6.18 7.68 9.38 11.08 12.78 14.68 16.58 18.48 20.48 22.58 24.68 26.88 29.18 31.48 33.88 36.28 38.78 41.38 43.98 46.68 49.38 52.18 55.08 57.98 60.98 63.98 Object wellpath 27.4E 27.4E 27.5E 27.5E 27.6E 1499.5 1510.6 1521. 7 1532.8 1543.9 M.D. T.V.D. 1499.5 1510.6 1521.7 1532.8 1543.9 1555.0 1566.1 1577.2 1588.4 1599.6 1610.6 1621.7 1632.8 1643.9 1655.0 1666.1 1677.2 1688.3 1699.4 1710.4 1721. 5 1732.5 1743.6 1754.6 1765.6 1776.6 1787.7 1798.7 1809.7 1820.7 1831.6 1842.6 1853.5 1864.5 1875.4 1886.3 1897.3 1908.1 1919.0 1929.9 1940.7 1951. 5 1962.4 1973.1 1983.9 1994.8 2005.5 2016.3 2027.0 2037.7 2048.4 e CLEARANCE LI8TING Page 3 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 14-6 Rect Coordinates Horiz Minim Bearing Dist 97.3N 97.2N 97.2N 97.1N 97.0N 96.9N 96.8N 96.7N 96.6N 96.5N 96.4N 96.3N 96.2N 96.1N 96. ON 95.9N 95.8N 95.7N 95.6N 95.5N 95.4N 95.3N 95.2N 95.1N 95.0N 94.9N 94.8N 94.7N 94.6N 94.5N 94.4N 94.3N 94.2N 94.1N 94.0N 93.9N 93.8N 93.7N 93.6N 93.5N 93.4N 93.3N 93.2N 93.0N 92.9N 92.8N 92.7N 92.6N 92 .5N 92.4N 92.3N 40.8E 40.9E 41.0E 41.1E 41.3E 41.4E 41. 5E 41.7E 41.8E 41. 9E 42.1E 42.2E 42.3E 42.5E 42.6E 42.7E 42.8E 42.9E 43.0E 43.1E 43.1E 43.2E 43.3E 43.4E 43.4E 43.5E 43.5E 43.6E 43.6E 43.7E 43.7E 43.7E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.9E 43.9E 43.9E 43.9E 44.0E 44.0E 44.0E 44.1E 44.1E 44.2E 9.0 9.1 9.2 9.2 9.3 9.3 9.3 9.2 9.2 9.2 9.1 9.0 8.9 8.8 8.6 8.4 8.3 8.1 7.9 7.6 7.4 7.1 6.9 6.6 6.3 95.3 96.4 97.6 98.9 100.2 TCy1 Dist 85.0* 85.0* 85.0 85.1 85.2 85.0* 85.0* 85.0 85.1 85.2 27.6E 27.7E 27.9E 28.0E 28.1E 1555.1 1566.2 1577.3 1588.5 1599.6 6.0 5.7 5.4 5.1 4.8 101.5 103.0 104.5 106.0 107.6 85.4 85.7 86.0 86.3 86.8 85.4 85.7 86.0 86.4 86.8 28.3E 28.5E 28.7E 28.9E 29.1E 1610.7 1621.8 1632.9 1644.0 1655.0 4.5 4.1 3.8 3.5 3.1 109.3 111.1 112.9 114.7 116.7 87.3 87.8 88.4 89.1 89.8 87.3 87.9 88.5 89.2 90.0 29.4E 29.6E 29.9E 30.2E 30.6E 1666.1 1677.2 1688.4 1699.4 1710.5 2.8 2.5 2.1 1.8 1.5 118.7 120.7 122.9 125.1 127 .3 90.5 91. 4 92.3 93.2 94.2 90.8 91. 6 92.6 93.6 94.6 30.9E 31. 2E 31. 6E 32.0E 32.4E 1721.5 1732.6 1743.6 1754.6 1765.7 1.2 0.8 0.5 0.2 359.9 129.6 132.0 134.4 137.0 139.5 95.8 97.0 98.2 99.5 100.9 102.4 103.9 105.5 107.1 108.9 110.7 112.5 114.5 116.5 118.6 120.7 122.9 125.3 127.6 130.1 132.6 135.2 137.9 140.7 143.5 146.4 149.4 152.5 155.7 158.9 162.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 32.8E 33.3E 33.7E 34.2E 34.7E 1776.7 1787.8 1798.8 1809.7 1820.7 35.2E 35.7E 36.3E 36.8E 37.4E 1831.7 1842.6 1853.6 1864.5 1875.4 38.0E 38.6E 39.2E 39.9E 40.5E 1886.4 1897.3 1908.2 1919.1 1929.9 41.2E 41.9E 42.6E 43.4E 44.1E 1940.8 1951.6 1962.4 1973.2 1984.0 44.9E 45.6E 46.4E 47.2E 48.1E 1994.8 2005.6 2016.3 2027 .1 2037.8 48.9E 2048.5 359.6 359.4 359.1 358.8 358.5 142.2 144.9 147.6 150.4 153.3 358.3 156.3 e e MARATHON Oil Company CLEARANCE LISTING Page 4 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object wellpath MSS <9768 - 10217> DepthShifted"KUI4X-6,Pad 14-6 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2059.1 2059.1 92 .2N 44.2E 358.0 159.3 165.6 2077.8 2068.0 70.2S 50.7E 2069.8 2069.7 92. ON 44.3E 357.7 162.4 169.1 2088.9 2078.6 73.4S 51.6E 2080.4 2080.4 91.9N 44.3E 357.5 165.5 172.7 2100.0 2089.2 76.7S 52.5E 2091. 2 2091.1 91.8N 44.4E 357.3 168.7 176.3 2111.1 2099.7 80.0S 53.4E 2101. 8 2101.7 91.7N 44.4E 357.0 172.0 180.1 2122.2 2110.3 83.4S 54.3E 2112.3 2112.3 91.6N 44.5E 356.8 175.3 183.9 2133.3 2120.8 86.9S 55.3E 2122.9 2122.8 91.5N 44.6E 356.6 178.7 187.8 2144.4 2131.3 90.4S 56.3E 2133.4 2133.4 91.4N 44.6E 356.3 182.1 191.8 2155.6 2141. 7 94.0S 57.3E 2144.0 2143.9 91. 2N 44.7E 356.1 185.6 195.9 2166.7 2152.2 97.6S 58.3E 2154.4 2154.4 91.1N 44.8E 355.9 189.2 200.1 2177.8 2162.6 101.3S 59.3E 2164.9 2164.9 91. ON 44.8E 355.7 192.8 204.3 2188.9 2173.0 105.0S 60.3E 2175.4 2175.3 90.9N 44.9E 355.5 196.5 208.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861. 8 874.2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911.6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961. 5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011. 5 1024.0 1036.5 1049.0 1061. 5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O.ON O.ON O. ON O.ON O. ON O. ON O.ON O. ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N LON 1. 2N 1. 4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11.7N 11. 9N 12.2N 12.4N 12.6N 12.8N 12.9N 13.1N 13.2N 13.3N 13.3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21. 2E 21.9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27.2E 27.3E 27.4E 27.4E 27.4E 27.4E 27.4E Object wellpath O.ow O.OW O.OW O.OW O.OW 0.1 100.3 200.1 300.0 400.0 M.D. T.V.D. 0.1 100.3 200.1 300.0 400.0 500.0 512.5 525.0 537.7 550.2 562.7 575.2 587.7 600.2 612.7 625.2 637.7 650.2 662.6 675.1 687.7 700.2 712.6 725.1 737.6 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911.9 924.4 936.9 949.3 961. 8 974 .3 986.8 999.3 1011. 8 1024.3 1036.7 1049.2 1061.7 1074.2 1086.7 1099.2 1199.2 1299.2 13 99.4 e CLEARANCE LISTING Page 5 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6,Pad 14-6 Rect Coordinates Horiz Minim Bearing Dist 100.2N 100.0N 99.7N 99.6N 99.7N 99.8N 99.8N 99.9N 99.9N 99.9N 99.9N 99.9N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.7N 99.7N 99.7N 99.7N 99.7N 99.6N 99.6N 99.5N 99.4N 99.4N 99.4N 99.4N 99.3N 99.3N 99.3N 99.3N 99.2N 99.2N 99.2N 99.1N 99.1N 99.1N 99.0N 99.0N 99.0N 99.0N 98.9N 98.9N 98.6N 98.3N 97.9N 41.9E 41. 9E 42.0E 41. 9E 41.6E 41.3E 41. 3E 41. 2E 41. 2E 41.1E 41.1E 41.0E 41. OE 40.9E 40.9E 40.8E 40.8E 40.7E 40.6E 40.6E 40.5E 40.5E 40.4E 40.4E 40.3E 40.2E 40.0E 39.7E 39.7E 39.6E 39.5E 39.4E 39.4E 39.3E 39.2E 39.1E 39.1E 39.0E 38.9E 38.8E 38.8E 38.7E 38.7E 38.6E 38.6E 38.5E 38.5E 38.5E 38.5E 39.0E 39.8E 22.7 22.8 22.8 22.8 22.7 108.6 108.4* 108.2* 108.1* 108.1* TCy1 Dist 108.6 108.4* 108.2* 108.1* 108.1* 108.0* 108.0* 107.9* 107.8* 107.7* 107.5* 107.2* 107.0* 106.6* 106.3* 105.9* 105.4* 105.0* 104.5* 103.9* 103.3* 102.7* 102.0* 101. 3* 100.6* 99.6* 96.5* 93.5* 92 .8* 92.1* 99.8* 96.7* 93.7* 92.9* 92 .2* O.OW O.OE O.lE 0.2E 0.4E 500.0 512.5 525.0 537.7 550.2 22.5 22.4 22.4 22.3 22.2 108.0* 108.0* 107.9* 107.8* 107.7* 91.5* 90.9* 90.3* 89.8* 89.4* 91.6* 91. 0* 90.4* 89.9* 89.4* 0.6E 0.9E 1. 2E 1. 6E 2.0E 562.7 575.2 587.7 600.2 612.7 22.1 22.0 21.8 21. 7 21. 5 107.5* 107.2* 106.9* 106.6* 106.2* 88.9* 88.5* 88.1* 87.8* 87.5* 89.0* 88.5* 88.2* 87.8* 87.5* 2.5E 3.0E 3.5E 4.1E 4.8E 625.2 637.7 650.2 662.6 675.1 21. 3 21. 0 20.8 20.5 20.2 105.8* 105.4* 104.9* 104.4* 103.8* 87.2* 87.0* 86.8* 86.6* 86.5* 87.2* 87.0* 86.8* 86.6* 86.5* 5.5E 6.3E 7.1E 7.9E 8.8E 687.7 700.2 712.6 725.1 737.6 19.8 19.5 19.1 18.7 18.3 103.2* 102.5* 101.9* 101.2* 100.4* 86.4* 86.3* 86.2* 86.0* 85.7* 85.4* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911.9 924.4 936.9 949.3 961. 8 974.3 986.8 999.3 1011. 8 1024.3 1036.8 1049.3 1061.8 1074.2 1086.7 1099.2 1199.2 1299.2 1399.4 17 .8 15.8 13.7 13.1 12.6 12.1 11.6 11.1 10.7 10.3 9.9 9.5 9.2 8.8 8.5 8.3 8.0 7.8 7.7 7.5 7.4 7.4 7.4 7.4 7.8 86.4* 86.3* 86.2* 86.0* 85.7* 8.3 85.4* e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1500.0 1511.1 1522.2 1533.3 1544.4 1499.0 1510.1 1521. 2 1532.3 1543.4 1555.6 1566.7 1577.8 1588.9 1600.0 1554.5 1565.6 1576.7 1587.8 1598.9 1611.1 1622.2 1633.3 1644.4 1655.6 1610.0 1621.1 1632.2 1643.3 1654.4 1666.7 1677.8 1688.9 1700.0 1711.1 1665.4 1676.5 1687.6 1698.6 1709.7 1722.2 1733.3 1744.4 17 55.6 1766.7 1720.7 1731.7 1742.8 1753.8 1764.8 1777.8 1788.9 1800.0 1811.1 1822.2 1775.8 1786.8 1797.8 1808.7 1819.7 1833.3 1844.4 1855.6 1866.7 1877.8 1830.6 1841. 6 1852.5 1863.4 1874.3 1888.9 1900.0 1911.1 1922.2 1933.3 1885.2 1896.1 1906.9 1917.8 1928.6 1944.4 1955.6 1966.7 1977.8 1988.9 1939.4 1950.2 1961.0 1971. 8 1982.6 2000.0 2011.1 2022.2 2033.3 2044.4 1993.3 2004.0 2014.7 2025.4 2036.1 2055.6 2046.7 13.4N 13.3N 13 .3N 13.1N 12.9N 12.6N 12.3N 11. 9N 11. 4N 10.9N 10.3N 9.6N 8.9N 8.1N 7.3N 6.4N 5.4N 4.4N 3.3N 2.1N 0.9N 0.3S 1. 7S 3.1S 4.5S 6.1S 7.6S 9.3S 11.0S 12.7S 14.6S 16.5S 18.4S 20.4S 22.5S 24.6S 26.8S 29.1S 31.4S 33.8S 36.2S 38.7S 41. 3S 43.9S 46.6S 49.3S 52.1S 55.0S 57.9S 60.9S 63.9S 27.6E 27.7E 27.9E 28.0E 28.1E Object we11path 27.4E 27.4E 27.5E 27.5E 27.6E 1499.5 1510.6 1521. 7 1532.8 1543.9 M.D. T.V.D. 1499.5 1510.6 1521.7 1532.8 1543.9 1555.0 1566.1 1577.2 1588.4 1599.6 1610.6 1621.7 1632.8 1643.9 1655.0 1666.1 1677.2 1688.3 1699.4 1710.4 1721. 5 17 32.5 1743.6 1754.6 1765.6 1776.6 1787.7 17 98.7 1809.7 1820.7 1831.6 1842.6 1853.5 1864.5 1875.4 1886.3 1897.3 1908.1 1919.0 1929.9 1940.7 1951.5 1962.4 1973.1 1983.9 1994.8 2005.5 2016.3 2027.0 2037.7 2048.4 e CLEARANCE LISTING Page 6 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6,Pad 14-6 Rect Coordinates Horiz Min'm Bearing Dist 97.3N 97.2N 97.2N 97.1N 97.0N 96.9N 96.8N 96.7N 96.6N 96.5N 96.4N 96.3N 96.2N 96.1N 96.0N 95.9N 95.8N 95.7N 95.6N 95.5N 95.4N 95.3N 95.2N 95.1N 95.0N 94.9N 94.8N 94.7N 94.6N 94.5N 94.4N 94.3N 94.2N 94.1N 94.0N 93.9N 93.8N 93.7N 93.6N 93.5N 93.4N 93.3N 93.2N 93.0N 92.9N 92 .8N 92.7N 92.6N 92.5N 92.4N 92 .3N 40.8E 40.9E 41.0E 41. IE 41. 3E 41.4E 41. 5E 41. 7E 41.8E 41.9E 42.1E 42.2E 42.3E 42.5E 42.6E 42.7E 42.8E 42.9E 43.0E 43.1E 43.1E 43.2E 43.3E 43.4E 43.4E 43.5E 43.5E 43.6E 43.6E 43.7E 43.7E 43.7E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.8E 43.9E 43.9E 43.9E 43.9E 44.0E 44.0E 44.0E 44.1E 44.1E 44.2E 9.0 9.1 9.2 9.2 9.3 9.3 9.3 9.2 9.2 9.2 9.1 9.0 8.9 8.8 8.6 8.4 8.3 8.1 7.9 7.6 7.4 7.1 6.9 6.6 6.3 95.3 96.4 97.6 98.9 100.2 TCy1 Dist 85.0* 85.0* 85.0 85.1 85.2 85.0* 85.0* 85.0 85.1 85.2 1555.1 1566.2 1577.3 1588.5 1599.6 28.3E 28.5E 28.7E 28.9E 29.1E 1610.7 1621. 8 1632.9 1644.0 1655.0 6.0 5.7 5.4 5.1 4.8 101. 5 103.0 104.5 106.0 107.6 85.4 85.7 86.0 86.3 86.8 85.4 85.7 86.0 86.4 86.8 29.4E 29.6E 29.9E 30.2E 30.6E 1666.1 1677.2 1688.4 1699.4 1710.5 4.5 4.1 3.8 3.5 3.1 109.3 111.1 112.9 114.7 116.7 87.3 87.8 88.4 89.1 89.8 87.3 87.9 88.5 89.2 90.0 30.9E 31. 2E 31.6E 32.0E 32.4E 1721. 5 17 32.6 1743.6 1754.6 1765.7 2.8 2.5 2.1 1.8 1.5 118.7 120.7 122.9 125.1 127.3 90.5 91. 4 92 .3 93.2 94.2 90.8 91. 6 92.6 93.6 94.6 32.8E 33.3E 33.7E 34.2E 34.7E 1776.7 1787.8 17 98.8 1809.7 1820.7 1.2 0.8 0.5 0.2 359.9 129.6 132.0 134.4 137.0 139.5 95.8 97.0 98.2 99.5 100.9 102.4 103.9 105.5 107.1 108.9 110.7 112.5 114.5 116.5 118.6 120.7 122.9 125.3 127.6 130.1 132.6 135.2 137.9 140.7 143.5 146.4 149.4 152.5 155.7 158.9 162.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level). Total Dogleg for well path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 35.2E 35.7E 36.3E 36.8E 37.4E 1831. 7 1842.6 1853.6 1864.5 1875.4 38.0E 38.6E 39.2E 39.9E 40.5E 1886.4 1897.3 1908.2 1919.1 1929.9 41. 2E 41. 9E 42.6E 43.4E 44.1E 1940.8 1951.6 1962.4 1973.2 1984.0 44.9E 45.6E 46.4E 47.2E 48.1E 1994.8 2005.6 2016.3 2027.1 2037.8 48.9E 2048.5 359.6 359.4 359.1 358.8 358.5 142.2 144.9 147.6 150.4 153.3 358.3 156.3 e e MARATHON Oil Company CLEARANCE LISTING Page 7 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T. V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2059.1 2059.1 92.2N 44.2E 358.0 159.3 165.6 2077.8 2068.0 70.2S 50.7E 2069.8 2069.7 92.0N 44.3E 357.7 162.4 169.1 2088.9 2078.6 73.4S 51.6E 2080.4 2080.4 91. 9N 44.3E 357.5 165.5 172.7 2100.0 2089.2 76.7S 52.5E 2091.2 2091.1 91.8N 44.4E 357.3 168.7 176.3 2111.1 2099.7 80.0S 53.4E 2101. 8 2101.7 91.7N 44.4E 357.0 172.0 180.1 2122.2 2110.3 83.4S 54.3E 2112.3 2112.3 91.6N 44.5E 356.8 175.3 183.9 2133.3 2120.8 86.9S 55.3E 2122.9 2122.8 91. 5N 44.6E 356.6 178.7 187.8 2144.4 2131. 3 90.4S 56.3E 2133.4 2133.4 91.4N 44.6E 356.3 182.1 191. 8 2155.6 2141. 7 94.0S 57.3E 2144.0 2143.9 91.2N 44.7E 356.1 185.6 195.9 2166.7 2152.2 97.6S 58.3E 2154.4 2154.4 91.1N 44.8E 355.9 189.2 200.1 2177.8 2162.6 101.3S 59.3E 2164.9 2164.9 91. ON 44.8E 355.7 192.8 204.3 2188.9 2173.0 105.0S 60.3E 2175.4 2175.3 90.9N 44.9E 355.5 196.5 208.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861.8 874 .2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911.6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961. 5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011.5 1024.0 1036.5 1049.0 1061. 5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O.ON O.ON O.ON O. ON O.ON O.ON O.ON O.ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N 1. ON 1.2N 1.4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11. 7N 11. 9N 12.2N 12.4N 12.6N 12.8N 12.9N 13.1N 13.2N 13.3N 13.3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21. 2E 21.9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27.2E 27.3E 27.4E 27.4E 27.4E 27.4E 27.4E Object we11path O.Ow O.OW O.OW O.OW O.OW 8.1 108.3 208.1 308.0 408.0 M.D. T.V.D. 0.1 100.3 200.1 300.0 400.0 500.0 512.5 525.0 537.7 550.2 562.7 575.2 587.7 600.2 612.7 625.2 637.7 650.2 662.6 675.1 687.7 700.2 712.6 725.1 737.6 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911.9 924.4 936.9 949.3 961. 8 974.3 986.8 999.3 1011.8 1024.3 1036.7 1049.2 1061. 7 1074.2 1086.7 1099.2 1199.2 1299.2 1399.4 e CLEARANCE LISTING Page 8 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 MSS <9776 - 10225>"KU14X-6,Pad 14-6 Rect Coordinates 100.2N 100.0N 99.7N 99.6N 99.7N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.7N 99.7N 99.7N 99.7N 99.6N 99.6N 99.5N 99.4N 99.4N 99.4N 99.4N 99.3N 99.3N 99.3N 99.3N 99.2N 99.2N 99.2N 99.2N 99.1N 99.1N 99.1N 99.0N 99.0N 99.0N 98.9N 98.9N 98.9N 98.6N 98.3N 97.9N 41.9E 41.9E 42.0E 41.9E 41. 6E 41.3E 41. 3E 41.2E 41. 2E 41.1E 41.1E 41. OE 41. OE 40.9E 40.9E 40.8E 40.8E 40.7E 40.7E 40.6E 40.5E 40.5E 40.4E 40.4E 40.3E 40.2E 40.0E 39.7E 39.7E 39.6E 39.5E 39.4E 39.4E 39.3E 39.2E 39.2E 39.1E 39.0E 38.9E 38.8E 38.8E 38.7E 38.7E 38.6E 38.6E 38.5E 38.5E 38.5E 38.5E 39.0E 39.8E Horiz Bearing Min'm Dist TCy1 Dist 22.7 22.8 22.8 22.8 22.7 108.6 108.4* 108.2* 108.1* 108.1* 108.6 108.4* 108.2* 108.1* 108.1* O.OW O.OE O.lE 0.2E 0.4E 508.0 520.5 533.0 545.7 558.2 22.5 22.4 22.4 22.3 22.2 108.0* 108.0* 107.9* 107.8* 107.6* 108.0* 108.0* 107.9* 107.8* 107.7* 0.6E 0.9E 1.2E 1. 6E 2.0E 570.7 583.2 595.7 608.2 620.7 22.1 22.0 21. 8 21. 7 21.5 107.4* 107.2* 106.9* 106.6* 106.2* 107.5* 107.2* 106.9* 106.6* 106.3* 2.5E 3.0E 3.5E 4.1E 4.8E 633.2 645.7 658.2 670.6 683.1 21. 3 21.0 20.8 20.5 20.2 105.8* 105.4* 104.9* 104.3* 103.8* 105.9* 105.4* 105.0* 104.4* 103.9* 5.5E 6.3E 7.1E 7.9E 8.8E 695.7 708.2 720.6 733.1 745.6 19.8 19.5 19.1 18.7 18.3 103.2* 102.5* 101.9* 101.1* 100.4* 103.3* 102.7* 102.0* 101.3* 100.6* 758.0 807.8 857.6 870.1 882.5 895.0 907.4 919.9 932.4 944.9 957.3 969.8 982.3 994.8 1007.3 1019.8 1032.3 1044.8 1057.3 1069.8 1082.2 1094.7 1107.2 1207.2 1307.2 1407.4 17.8 15.8 13.7 13 .1 12.6 99.6* 96.5* 93.5* 92 .8* 92.1* 99.8* 96.7* 93.7* 92.9* 92.2* 12.1 11. 6 11.1 10.7 10.3 91.5* 90.9* 90.3* 89.8* 89.3* 91.6* 91.0* 90.4* 89.9* 89.4* 9.9 9.5 9.2 8.8 8.5 88.9* 88.5* 88.1* 87.8* 87.5* 88.9* 88.5* 88.2* 87.8* 87.5* 8.3 8.0 7.8 7.7 7.5 87.2* 87.0* 86.8* 86.6* 86.5* 87.2* 87.0* 86.8* 86.6* 86.5* 7.5 7.4 7.4 7.4 7.8 86.3* 86.3* 86.2* 85.9* 85.7* 86.3* 86.3* 86.2* 85.9* 85.7* 8.3 85.4* 85.4* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - e MARATHON Oil Company CLEARANCE LISTING Page 9 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path MSS <9776 - 10225>"KU14X-6,Pad 14-6 Horiz MinIm TCy1 M.D. T.V.D. Rect Coordinates M.D. T. V.D. Rect Coordinates Bearing Dist Dist 1500.0 1499.0 13.4N 27.4E 1507.5 14 99.5 97.3N 40.8E 9.0 85.0* 85.0* 1511.1 1510.1 13.3N 27.4E 1518.6 1510.6 97.2N 40.9E 9.1 84.9* 84.9* 1522.2 1521. 2 13.3N 27.5E 1529.7 1521.7 97.1N 41.0E 9.2 85.0 85.0 1533.3 1532.3 13 .1N 27.5E 1540.8 1532.8 97.1N 41.1E 9.2 85.1 85.1 1544.4 1543.4 12.9N 27.6E 1551.9 1543.9 97.0N 41. 3E 9.3 85.2 85.2 1555.6 1554.5 12.6N 27.6E 1563.1 1555.0 96.9N 41.4E 9.3 85.4 85.4 1566.7 1565.6 12.3N 27.7E 1574.2 1566.1 96.8N 41.5E 9.3 85.7 85.7 1577.8 1576.7 11. 9N 27.9E 1585.3 1577.2 96.7N 41.7E 9.3 86.0 86.0 1588.9 1587.8 11. 4N 28.0E 1596.5 1588.4 96.6N 41. 8E 9.2 86.3 86.4 1600.0 1598.9 10.9N 28.1E 1607.6 1599.6 96.5N 42.0E 9.2 86.8 86.8 1611.1 1610.0 10.3N 28.3E 1618.7 1610.6 96.4N 42.1E 9.1 87.2 87.3 1622.2 1621. 1 9.6N 28.5E 1629.8 1621 . 7 96.3N 42.2E 9.0 87.8 87.9 1633.3 1632.2 8.9N 28.7E 1640.9 1632.8 96.2N 42.3E 8.9 88.4 88.5 1644.4 1643.3 8.1N 28.9E 1652.0 1643.9 96.1N 42.5E 8.8 89.0 89.2 1655.6 1654.4 7.3N 29.1E 1663.0 1655.0 96.0N 42.6E 8.6 89.8 90.0 1666.7 1665.4 6.4N 29.4E 1674.1 1666.1 95.9N 42.7E 8.5 90.5 90.8 1677.8 1676.5 5.4N 29.6E 1685.2 1677.2 95.8N 42.8E 8.3 91. 4 91. 6 1688.9 1687.6 4.4N 29.9E 1696.4 1688.3 95.7N 42.9E 8.1 92 .2 92.6 1700.0 1698.6 3.3N 30.2E 1707.4 1699.4 95.6N 43.0E 7.9 93.2 93.6 1711.1 1709.7 2.1N 30.6E 1718.5 1710.4 95.5N 43.1E 7.6 94.2 94.6 1722.2 1720.7 0.9N 30.9E 1729.5 1721. 5 95.4N 43.2E 7.4 95.3 95.7 1733.3 1731.7 0.3S 31. 2E 1740.6 1732.5 95.3N 43.2E 7.1 96.4 96.9 1744.4 1742.8 1. 7S 31.6E 1751.6 1743.6 95.2N 43.3E 6.9 97.6 98.2 1755.6 17 53.8 3.1S 32.0E 17 62.6 1754.6 95.1N 43.4E 6.6 98.8 99.5 1766.7 1764.8 4.5S 32.4E 1773.7 1765.6 95.0N 43.4E 6.3 100.2 100.9 1777.8 1775.8 6.1S 32.8E 1784.7 1776.6 94.9N 43.5E 6.0 101. 5 102.3 1788.9 1786.8 7.6S 33.3E 1795.8 1787.7 94.8N 43.5E 5.7 103.0 103.9 1800.0 1797.8 9.3S 33.7E 1806.8 1798.7 94.7N 43.6E 5.4 104.5 105.5 1811.1 1808.7 11.0S 34.2E 1817.7 1809.7 94.6N 43.6E 5.1 106.0 107.1 1822.2 1819.7 12.7S 34.7E 1828.7 1820.7 94.5N 43.7E 4.8 107.6 108.8 1833.3 1830.6 14.6S 35.2E 1839.7 1831.6 94.4N 43.7E 4.5 109.3 110.6 1844.4 1841. 6 16.5S 35.7E 1850.6 1842.6 94.3N 43.7E 4.1 111.1 112.5 1855.6 1852.5 18.4S 36.3E 1861.6 1853.5 94.2N 43.8E 3.8 112.9 114.4 1866.7 1863.4 20.4S 36.8E 1872.5 1864.5 94.1N 43.8E 3.5 114.7 116.5 1877.8 1874.3 22.5S 37.4E 1883.4 1875.4 94.0N 43.8E 3.1 116.7 118.5 1888.9 1885.2 24.6S 38.0E 1894.4 1886.3 93.9N 43.8E 2.8 118.7 120.7 1900.0 1896 .1 26.8S 38.6E 1905.3 1897.3 93.8N 43.8E 2.5 120.7 122.9 1911.1 1906.9 29.1S 39.2E 1916.2 1908.1 93.7N 43.8E 2.1 122.8 125.2 1922.2 1917.8 31.4S 39.9E 1927 .1 1919.0 93.6N 43.8E 1.8 125.0 127.6 1933.3 1928.6 33.8S 40.5E 1937.9 1929.9 93.5N 43.8E 1.5 127.3 130.1 1944.4 1939.4 36.2S 41. 2E 1948.8 1940.7 93.4N 43.8E 1.2 129.6 132.6 1955.6 1950.2 38.7S 41.9E 1959.6 1951. 5 93.2N 43.9E 0.8 132.0 135.2 1966.7 1961. 0 41.3S 42.6E 1970.4 1962.3 93.1N 43.9E 0.5 134.4 137.9 1977 . 8 1971.8 43.9S 43.4E 1981. 2 1973.1 93.0N 43.9E 0.2 136.9 140.7 1988.9 1982.6 46.6S 44.1E 1992.0 1983.9 92.9N 43.9E 359.9 139.5 143.5 2000.0 1993.3 49.3S 44.9E 2002.8 1994.8 92.8N 44.0E 359.6 142.1 146.4 2011.1 2004.0 52.1S 45.6E 2013.6 2005.5 92.7N 44.0E 359.4 144.8 149.4 2022.2 2014.7 55.0S 46.4E 2024.3 2016.3 92.6N 44.0E 359.1 147.6 152.5 2033.3 2025.4 57.9S 47.2E 2035.1 2027.0 92.5N 44.1E 358.8 150.4 155.7 2044.4 2036.1 60.9S 48.1E 2045.8 2037.7 92.4N 44.1E 358.5 153.3 158.9 2055.6 2046.7 63.9S 48.9E 2056.5 2048.4 92.3N 44.2E 358.3 156.3 162.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 10 pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object wellpath MSS <9776 - 10225>"KU14X-6,Pad 14-6 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2067.1 2059.1 92.1N 44.2E 358.0 159.3 165.6 2077.8 2068.0 70.28 50.7E 2077.8 2069.7 92 .ON 44.3E 357.7 162.3 169.1 2088.9 2078.6 73.4S 51. 6E 2088.4 2080.4 91.9N 44.3E 357.5 165.5 172.7 2100.0 2089.2 76.78 52.5E 2099.2 2091.1 91.8N 44.4E 357.3 168.7 176.3 2111.1 2099.7 80.0S 53.4E 2109.8 2101. 7 91.7N 44.4E 357.0 171.9 180.1 2122.2 2110.3 83.48 54.3E 2120.3 2112.3 91.6N 44.5E 356.8 175.3 183.9 2133.3 2120.8 86.98 55.3E 2130.9 2122.8 91. 5N 44.6E 356.6 178.7 187.8 2144.4 2131.3 90.48 56.3E 2141.4 2133.4 91. 3N 44.6E 356.3 182.1 191.8 2155.6 2141.7 94.0S 57.3E 2152.0 2143.9 91.2N 44.7E 356.1 185.6 195.9 2166.7 2152.2 97.6S 58.3E 2162.4 2154.4 91.1N 44.8E 355.9 189.2 200.0 2177.8 2162.6 101.38 59.3E 2172.9 2164.9 91. ON 44.9E 355.7 192.8 204.3 2188.9 2173.0 105.08 60.3E 2183.4 2175.3 90.9N 44.9E 355.5 196.5 208.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861.8 874.2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911.6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961. 5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011. 5 1024.0 1036.5 1049.0 1061. 5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O. ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N LON 1. 2N 1. 4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11. 7N 11. 9N 12.2N 12.4N 12.6N 12.8N 12.9N 13.1N 13.2N 13.3N 13.3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21. 2E 21. 9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27.2E 27.3E 27.4E 27.4E 27.4E 27.4E 27.4E Object we11path O. OW O.OW O.OW O. OW O.OW 8.1 108.3 208.1 308.0 408.0 M.D. T.V.D. 0.1 100.3 200.1 300.0 400.0 500.0 512.5 525.0 537.7 550.2 562.7 575.2 587.7 600.2 612.7 625.2 637.7 650.2 662.6 675.1 687.7 700.2 712.6 725.1 737.6 750.0 799.8 849.6 862.1 874.5 887.0 899.4 911.9 924.4 936.9 949.3 961. 8 974.3 986.8 999.3 1011.8 1024.3 1036.7 1049.2 1061.7 1074.2 1086.7 1099.2 1199.2 1299.2 1399.4 e CLEARANCE LISTING Page 11 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 GMS <0 - 9500>"KU14X-6,Pad 14-6 Rect Coordinates Horiz Min'm Bearing Dist 100.2N 100.0N 99.7N 99.6N 99.7N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.8N 99.7N 99.7N 99.7N 99.7N 99.6N 99.6N 99.5N 99.4N 99.4N 99.4N 99.4N 99.3N 99.3N 99.3N 99.3N 99.2N 99.2N 99.2N 99.2N 99.1N 99.1N 99.1N 99.0N 99.0N 99.0N 98.9N 98.9N 98.9N 98.6N 98.3N 97.9N 41. 9E 41.9E 42.0E 41.9E 41. 6E 41.3E 41. 3E 41. 2E 41.2E 41. IE 41.1E 41.0E 41. OE 40.9E 40.9E 40.8E 40.8E 40.7E 40.7E 40.6E 40.5E 40.5E 40.4E 40.4E 40.3E 40.2E 40.0E 39.7E 39.7E 39.6E 39.5E 39.4E 39.4E 39.3E 39.2E 39.2E 39.1E 39.0E 38.9E 38.8E 38.8E 38.7E 38.7E 38.6E 38.6E 38.5E 38.5E 38.5E 38.5E 39.0E 39.8E TCy1 Dist 22.7 22.8 22.8 22.8 22.7 108.6 108.4* 108.2* 108.1* 108.1* 108.6 108.4* 108.2* 108.1* 108.1* O.OW O.OE O.lE 0.2E 0.4E 508.0 520.5 533.0 545.7 558.2 22.5 22.4 22.4 22.3 22.2 108.0* 108.0* 107.9* 107.8* 107.6* 108.0* 108.0* 107.9* 107.8* 107.7* 0.6E 0.9E 1.2E 1. 6E 2.0E 570.7 583.2 595.7 608.2 620.7 22.1 22.0 21. 8 21. 7 21. 5 107.5* 107.2* 106.9* 106.6* 106.3* 2.5E 3.0E 3.5E 4.1E 4.8E 633.2 645.7 658.2 670.6 683.1 107.4* 107.2* 106.9* 106.6* 106.2* 21. 3 21. 0 20.8 20.5 20.2 105.8* 105.4* 104.9* 104.3* 103.8* 105.9* 105.4* 105.0* 104.4* 103.9* 5.5E 6.3E 7.1E 7.9E 8.8E 695.7 708.2 720.6 733.1 745.6 19.8 19.5 19.1 18.7 18.3 103.2* 102.5* 101.9* 101.1* 100.4* 103.3* 102.7* 102.0* 101. 3* 100.6* 758.0 807.8 857.6 870.1 882.5 895.0 907.4 919.9 932.4 944.9 957.3 969.8 982.3 994.8 1007.3 1019.8 1032.3 1044.8 1057.3 1069.8 1082.2 1094.7 1107.2 1207.2 1307.2 1407.4 17.8 15.8 13.7 13.1 12.6 99.6* 96.5* 93.5* 92.8* 92.1 * 99.8* 96.7* 93.7* 92.9* 92.2* 12.1 11. 6 11.1 10.7 10.3 91. 5* 90.9* 90.3* 89.8* 89.3* 91. 6* 91. 0* 90.4* 89.9* 89.4* 9.9 9.5 9.2 8.8 8.5 88.9* 88.5* 88.2* 87.8* 87.5* 88.9* 88.5* 88.1* 87.8* 87.5* 8.3 8.0 7.8 7.7 7.5 87.2* 87.0* 86.8* 86.6* 86.5* 87.2* 87.0* 86.8* 86.6* 86.5* 7.5 7.4 7.4 7.4 7.8 86.3* 86.3* 86.2* 85.9* 85.7* 86.3* 86.3* 86.2* 85.9* 85.7* 8.3 85.4* 85.4* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LI5TING Page 12 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object wellpath GM5 <0 - 9500>"KU14X-6,Pad 14-6 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1500.0 1499.0 13.4N 27.4E 1507.5 1499,5 97.3N 40.8E 9.0 85.0* 85.0* 1511.1 1510.1 13.3N 27 .4E 1518.6 1510.6 97.2N 40.9E 9.1 84.9* 84.9* 1522.2 1521.2 13.3N 27.5E 1529.7 1521.7 97.1N 41. OE 9.2 85.0 85.0 1533.3 1532.3 13.1N 27 .5E 1540.8 1532.8 97.1N 41.1E 9.2 85.1 85.1 1544.4 1543.4 12.9N 27.6E 1551.9 1543.9 97.0N 41.3E 9.3 85.2 85.2 1555.6 1554.5 12.6N 27.6E 1563.1 1555.0 96.9N 41. 4E 9.3 85.4 85.4 1566.7 1565.6 12.3N 27.7E 1574.2 1566.1 96.8N 41. 5E 9.3 85.7 85.7 1577.8 1576.7 11.9N 27.9E 1585.3 1577.2 96.7N 41.7E 9.3 86.0 86.0 1588.9 1587.8 11.4N 28.0E 1596.5 1588.4 96.6N 41.8E 9.2 86.3 86.4 1600.0 1598.9 10.9N 28.1E 1607.6 1599.6 96.5N 42.0E 9.2 86.8 86.8 1611.1 1610.0 10.3N 28.3E 1618.7 1610.6 96.4N 42.1E 9.1 87.2 87.3 1622.2 1621.1 9.6N 28.5E 1629.8 1621. 7 96.3N 42.2E 9.0 87.8 87.9 1633.3 1632.2 8.9N 28.7E 1640.9 1632.8 96.2N 42.3E 8.9 88.4 88.5 1644.4 1643.3 8.1N 28.9E 1652.0 1643.9 96.1N 42.5E 8.8 89.0 89.2 1655.6 1654.4 7.3N 29.1E 1663.0 1655.0 96.0N 42.6E 8.6 89.8 90.0 1666.7 1665.4 6.4N 29.4E 1674.1 1666.1 95.9N 42.7E 8.5 90.5 90.8 1677.8 1676.5 5.4N 29.6E 1685.2 1677 . 2 95.8N 42.8E 8.3 91. 4 91. 6 1688.9 1687.6 4.4N 29.9E 1696.4 1688.3 95.7N 42.9E 8.1 92.2 92.6 1700.0 1698.6 3.3N 30.2E 1707.4 1699.4 95.6N 43.0E 7.9 93.2 93.6 1711.1 1709.7 2.1N 30.6E 1718.5 1710.4 95.5N 43.1E 7.6 94.2 94.6 1722.2 1720.7 0.9N 30.9E 1729.5 1721. 5 95.4N 43.2E 7.4 95.3 95.7 17 33.3 1731.7 0.35 31. 2E 1740.6 1732.5 95.3N 43.2E 7.1 96.4 96.9 1744.4 1742.8 1. 75 31.6E 1751. 6 1743.6 95.2N 43.3E 6.9 97.6 98.2 1755.6 1753.8 3.15 32.0E 1762.6 1754.6 95.1N 43.4E 6.6 98.8 99.5 1766.7 1764.8 4.55 32.4E 1773.7 1765.6 95.0N 43.4E 6.3 100.2 100.9 1777.8 1775.8 6.15 32.8E 1784.7 1776.6 94.9N 43.5E 6.0 101.5 102.3 1788.9 1786.8 7.65 33.3E 1795.8 1787.7 94.8N 43.5E 5.7 103.0 103.9 1800.0 1797.8 9.35 33.7E 1806.8 1798.7 94.7N 43.6E 5.4 104.5 105.5 1811.1 1808.7 11.05 34.2E 1817.7 1809.7 94.6N 43.6E 5.1 106.0 107.1 1822.2 1819.7 12.75 34.7E 1828.7 1820.7 94.5N 43.7E 4.8 107.6 108.8 1833.3 1830.6 14.65 35.2E 1839.7 1831.6 94.4N 43.7E 4.5 109.3 110.6 1844.4 1841.6 16.55 35.7E 1850.6 1842.6 94.3N 43.7E 4.1 111.1 112.5 1855.6 1852.5 18.45 36.3E 1861.6 1853.5 94.2N 43.8E 3.8 112.9 114.4 1866.7 1863.4 20.45 36.8E 1872.5 1864.5 94.1N 43.8E 3.5 114.7 116.5 1877.8 1874.3 22.55 37.4E 1883.4 1875.4 94.0N 43.8E 3.1 116.7 118.5 1888.9 1885.2 24.65 38.0E 1894.4 1886.3 93.9N 43.8E 2.8 118.7 120.7 1900.0 1896.1 26.85 38.6E 1905.3 1897.3 93.8N 43.8E 2.5 120.7 122.9 1911.1 1906.9 29.15 39.2E 1916.2 1908.1 93.7N 43.8E 2.1 122.8 125.2 1922.2 1917.8 31.45 39.9E 1927.1 1919.0 93.6N 43.8E 1.8 125.0 127.6 1933.3 1928.6 33.85 40.5E 1937.9 1929.9 93.5N 43.8E 1.5 127 .3 130.1 1944.4 1939.4 36.25 41.2E 1948.8 1940.7 93.4N 43.8E 1.2 129.6 132.6 1955.6 1950.2 38.75 41.9E 1959.6 1951. 5 93.2N 43.9E 0.8 132.0 135.2 1966.7 1961.0 41. 35 42.6E 1970.4 1962.3 93.1N 43.9E 0.5 134.4 137.9 1977.8 1971.8 43.95 43.4E 1981. 2 1973.1 93.0N 43.9E 0.2 136.9 140.7 1988.9 1982.6 46.65 44.1E 1992.0 1983.9 92.9N 43.9E 359.9 139.5 143.5 2000.0 1993.3 49.35 44.9E 2002.8 1994.8 92.8N 44.0E 359.6 142.1 146.4 2011.1 2004.0 52.15 45.6E 2013.6 2005.5 92.7N 44.0E 359.4 144.8 149.4 2022.2 2014.7 55.05 46.4E 2024.3 2016.3 92.6N 44.0E 359.1 147.6 152.5 2033.3 2025.4 57.95 47.2E 2035.1 2027.0 92.5N 44.1E 358.8 150.4 155.7 2044.4 2036 .1 60.95 48.1E 2045.8 2037.7 92.4N 44.1E 358.5 153.3 158.9 2055.6 2046.7 63.95 48.9E 2056.5 2048.4 92 .3N 44.2E 358.3 156.3 162.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level; Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 13 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11pa th GMS <0 - 9500>"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2067.1 2059.1 92 .1N 44.2E 358.0 159.3 165.6 2077.8 2068.0 70.2S 50.7E 2077.8 2069.7 92. ON 44.3E 357.7 162.3 169.1 2088.9 2078.6 73.4S 51.6E 2088.4 2080.4 91. 9N 44.3E 357.5 165.5 172.7 2100.0 2089.2 76.7S 52.5E 2099.2 2091.1 91. 8N 44.4E 357.3 168.7 176.3 2111.1 2099.7 80.0S 53.4E 2109.8 2101. 7 91.7N 44.4E 357.0 171.9 180.1 2122.2 2110.3 83.4S 54.3E 2120.3 2112.3 91. 6N 44.5E 356.8 175.3 183.9 2133.3 2120.8 86.9S 55.3E 2130.9 2122.8 91. 5N 44.6E 356.6 178.7 187.8 2144.4 2131.3 90.4S 56.3E 2141.4 2133.4 91. 3N 44.6E 356.3 182.1 191. 8 2155.6 2141.7 94.0S 57.3E 2152.0 2143.9 91. 2N 44.7E 356.1 185.6 195.9 2166.7 2152.2 97.6S 58.3E 2162.4 2154.4 91. IN 44.8E 355.9 189.2 200.0 2177.8 2162.6 101. 3S 59.3E 2172.9 2164.9 91. ON 44.9E 355.7 192.8 204.3 2188.9 2173.0 105.0S 60.3E 2183.4 2175.3 90.9N 44.9E 355.5 196.5 208.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861.8 874.2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911.6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961.5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011. 5 1024.0 1036.5 1049.0 1061.5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O.ON O. ON O.ON O.ON O. ON O.ON O. ON O.ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N 1. ON 1. 2N 1. 4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11. 7N 11. 9N 12.2N 12.4N 12.6N 12.8N 12.9N 13.1N 13.2N 13.3N 13 .3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21.2E 21.9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27.2E 27 .3E 27.4E 27.4E 27.4E 27.4E 27.4E Object we11path O. ow O.OW O.OW O.OW O.OW 5.0 105.0 205.1 305.1 405.3 M.D. T.V.D. 0.0 100.0 200.1 300.1 400.3 500.7 513.2 525.7 538.2 551.2 563.7 576.2 588.7 601.2 613.7 626.2 638.7 651.7 664.2 676.7 689.2 701. 7 714.1 726.6 739.1 751. 6 801.4 850.8 863.3 875.7 888.2 900.7 913.1 925.6 937.6 950.1 962.6 975.1 987.6 1000.0 1012.5 1024.9 1037.4 1049.9 1062.4 1074.9 1087.4 1099.9 1199.9 1299.9 1400.3 e CLEARANCE LI5TING Page 14 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 INCLINATION ONLY"KU14-6,Pad 14-6 Rect Coordinates Horiz Minim Bearing Dist TCy1 Dist 68.45 68.45 68.45 68.45 68.35 68.25 68.25 68.25 68.25 68.15 68.15 68.15 68.15 68.05 68.05 68.05 68.05 67.95 67.95 67.95 67.85 67.85 67.75 67.75 67.75 67.65 67.45 67.35 67.35 67.25 67.25 67.25 67.15 67.15 67.15 67.15 67.05 67.05 67.05 67.05 67.05 66.95 66.95 66.95 66.95 66.95 66.95 66.95 66.75 66.55 66.45 141.9W 141. 9W 141.9W 141.9W 141. 7W 141.3W 141. 3W 141.2W 141. 2W 141.1W 141.0W 140.9W 140.8W 140.7W 140.6W 140.5W 140.4W 140.3W 140.2W 140. OW 13 9 . 9W 139.8W 139.6W 13 9. 5W 139.4W 13 9 . 2W 138.6W 138.1W 138. ow 13 7. 9W 137.8W 13 7. 7W 13 7. 6W 13 7. 5W 137.4W 13 7. 3W 13 7. 2W 137.1W 137.1W 137.0W 13 7. OW 136.9W 136.8W 13 6. 8W 13 6. 7W 136.7W 136 . 6W 13 6 . 6W 136.1W 135.5W 134.9W 244.3 244.3 244.3 244.3 244.3 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.2 244.1 244.1 244.1 244.1 244.1 244.1 244.1 244.1 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 244.0 243.9 243.9 243.9 243.9 243.9 243.9 243.9 243.9 243.9 243.8 157.5 157.5 157.5* 157.5* 157.3* 157.5 157.5 157.5* 157.5* 157.3* O.OW O.OE O.lE 0.2E 0.4E 505.7 518.2 530.7 543.2 556.2 157.0* 156.9* 156.9 157.0 157.1 157.0* 156.9* 156.9 157.0 157.1 0.6E 0.9E 1.2E 1. 6E 2.0E 568.7 581. 2 593.7 606.2 618.7 157.3 157.5 157.8 158.1 158.4 157.3 157.5 157.8 158.1 158.5 2.5E 3.0E 3.5E 4.1E 4.8E 631. 2 643.7 656.7 669.2 681.7 158.8 159.3 159.8 160.4 161. 0 158.9 159.4 160.0 160.5 161.2 5.5E 6.3E 7.1E 7.9E 8.8E 694.2 706.7 719.1 731. 6 744.1 161.6 162.3 163.1 163.9 164.8 161.9 162.6 163.4 164.3 165.2 756.6 806.4 855.8 868.3 880.7 893.2 905.7 918.2 930.6 942.6 955.1 967.6 980.1 992.6 1005.1 1017.6 1030.0 1042.5 1055.0 1067.5 1080.0 1092.5 1105.0 1205.0 1305.0 1405.3 165.7 169.4 173.2 174.2 175.1 166.1 169.9 173.8 174.7 175.5 175.9 176.7 177.5 178.2 178.8 176.3 177 .1 177.8 178.4 179.0 179.4 179.9 180.4 180.9 181. 3 179.6 180.1 180.6 181. 0 181.4 181.6 181.9 182.2 182.4 182.5 181.7 182.0 182.2 182.4 182.5 182.6 182.6 182.6* 182.1* 181. 5* 182.6 182.6 182.6* 182.1* 181.5* 180.8* 180.8* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1500.0 1511.1 1522.2 1533.3 1544.4 1499.0 1510.1 1521.2 1532.3 1543.4 1555.6 1566.7 1577.8 1588.9 1600.0 1554.5 1565.6 1576.7 1587.8 1598.9 1611.1 1622.2 1633.3 1644.4 1655.6 1610.0 1621.1 1632.2 1643.3 1654.4 1666.7 1677.8 1688.9 1700.0 1711.1 1665.4 1676.5 1687.6 1698.6 1709.7 1722.2 1733.3 1744.4 1755.6 1766.7 1720.7 1731.7 1742.8 1753.8 1764.8 1777.8 1788.9 1800.0 1811.1 1822.2 1775.8 1786.8 1797.8 1808.7 1819.7 1833.3 1844.4 1855.6 1866.7 1877.8 1830.6 1841.6 1852.5 1863.4 1874.3 1888.9 1900.0 1911.1 1922.2 1933.3 1885.2 1896.1 1906.9 1917.8 1928.6 1944.4 1955.6 1966.7 1977.8 1988.9 1939.4 1950.2 1961.0 1971.8 1982.6 2000.0 2011.1 2022.2 2033.3 2044.4 1993.3 2004.0 2014.7 2025.4 2036.1 2055.6 2046.7 13.4N 13.3N 13.3N 13.1N 12.9N 12.6N 12.3N 11. 9N 11. 4N 10.9N 10.3N 9.6N 8.9N 8.1N 7.3N 6.4N 5.4N 4.4N 3.3N 2.1N 0.9N 0.3S 1. 7S 3.1S 4.5S 6.1S 7.6S 9.3S 11. OS 12.7S 14.6S 16.5S 18.4S 20.4S 22.55 24.6S 26.8S 29.1S 31. 4S 33.8S 36.2S 38.7S 41. 3S 43.9S 46.6S 49.3S 52.1S 55.0S 57.95 60.95 63.95 Object wellpath 27.4E 27.4E 27.5E 27.5E 27.6E 1505.3 1516.4 1527.5 1538.6 1549.7 M.D. T.V.D. 1500.3 1511.4 1522.5 1533.6 1544.7 1555.8 1566.9 1578.0 1589.1 1600.6 1611.6 1622.7 1633.8 1644.9 1656.0 1667.1 1678.1 1689.2 1700.2 1711.3 1722.3 1733.3 1744.4 17 55.4 1766.4 1777.4 1788.4 1799.4 1810.3 1821. 3 1832.2 1843.2 1854.1 1865.0 1875.9 1886.8 1897.7 1908.6 1919.4 1930.2 1941.1 1951. 9 1962.6 1973.4 1984.2 1994.9 2005.6 2016.3 2027.0 2037.7 2048.4 e CLEARANCE LISTING Page 15 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 INCLINATION ONLY"KU14-6,Pad 14-6 Rect Coordinates Horiz Minim Bearing Dist 66.2S 66.15 66.15 66.15 66.15 66.0S 66.0S 66.0S 66.0S 66.0S 65.9S 65.9S 65.9S 65.8S 65.8S 65.8S 65.8S 65.7S 65.7S 65.7S 65.7S 65.6S 65.6S 65.6S 65.6S 65.5S 65.5S 65.5S 65.4S 65.4S 65.4S 65.3S 65.3S 65.3S 65.3S 65.2S 65.2S 65.2S 65.1S 65.1S 65.1S 65.1S 65.0S 65.0S 65.0S 64.9S 64.9S 64.9S 64.9S 64.8S 64.8S 13 4. 2W 134.1W 134. OW 133.9W 133.9W 133.8W 133.7W 133.6W 133.5W 133.4W 133.3W 133.2W 133.2W 133.1W 133. OW 132.9W 132.8W 132.7W 132.6W 132.5W 132.4W 132.3W 132.2W 132.1W 132. OW 131.9W 131. 8W 131.7W 131.6W 131. 5W 131.4W 131. 3W 131. 2W 131.1W 131. OW 130.9W 130.8W 130.7W 130.6W 130.5W 130.4W 13 O. 3W 130.2W 130.1W 130. OW 129.9W 129.8W 129.7W 129.6W 129.5W 129.4W TCyl Dist 243.8 243.8 243.8 243.9 243.9 180.1* 180.0* 17 9.9* 179.8* 179.7* 180.1* 180.1* 180.0* 179.8* 179.7* 27.6E 27.7E 27.9E 28.0E 28.1E 1560.8 1572.0 1583.1 1594.2 1605.6 244.0 244.1 244.3 244.4 244.6 17 9.6* 179.4* 179.2* 179.1* 17 8.9* 179.6* 179.4* 179.3* 179.1* 178.9* 28.3E 28.5E 28.7E 28.9E 29.1E 1616.7 1627.8 1638.9 1649.9 1661.0 244.8 245.0 245.2 245.5 245.7 178.7* 178.5* 178.3* 178.1* 177.8* 178.7* 178.5* 178.3* 178.1* 177.9* 29.4E 29.6E 29.9E 30.2E 30.6E 1672 .1 1683.2 1694.2 1705.3 1716.3 246.0 246.3 246.7 247.0 247.4 177.6* 177.4* 177.2* 176.9* 176.7* 30.9E 31. 2E 31.6E 32.0E 32.4E 1727.4 1738.4 1749.4 1760.4 1771.4 177.6* 177.4* 177.1* 176.9* 176.6* 247.8 248.2 248.7 249.2 249.6 176.4* 176.2* 175.9* 175.7* 175.4* 32.8E 33.3E 33.7E 34.2E 34.7E 1782.4 1793.4 1804.4 1815.4 1826.3 176.4* 176.1* 175.9* 17 5.6* 175.4* 250.2 250.7 251. 2 251.8 252.4 175.2* 175.0* 174.7* 174.6* 174.4* 175.2* 175.0* 174.8* 174.6* 174.4* 35.2E 35.7E 36.3E 36.8E 37.4E 1837.3 1848.2 1859.1 1870.0 1880.9 253.0 253.7 254.4 255.0 255.8 174.2* 174.1 * 173.9* 173.8* 173.8* 174.2* 174.1* 173.9* 173.8* 173.8* 38.0E 38.6E 39.2E 39.9E 40.5E 1891. 9 1902.7 1913.6 1924.5 1935.3 256.5 257.2 258.0 258.8 259.6 173.7* 173.7* 173.7 173.8 173.9 41.2E 41. 9E 42.6E 43.4E 44.1E 1946.1 1956.9 1967.7 1978.5 1989.2 173.7* 173.7* 173.7 173.8 173.9 260.5 261.3 262.2 263.1 264.0 174.0 174.2 174.4 174.7 175.1 174.0 174.2 174.5 174.8 175.2 44.9E 45.6E 46.4E 47.2E 48.1E 2000.0 2010.7 2021.4 2032.1 2042.8 264.9 265.8 266.8 267.7 268.7 175.4 175.9 176.4 177.0 177.6 175.6 176.1 176.6 177.3 178.0 48.9E 2053.4 269.7 178.3 178.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 16 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path INCLINATION ONLY"KU14-6,Pad 14-6 Horiz MinIm TCyl M.D. T. V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2064.0 2059.0 64.8S 129.3W 270.7 179.1 179.6 2077.8 2068.0 70.2S 50.7E 2074.7 2069.6 64.7S 129.2W 271.7 180.0 180.6 2088.9 2078.6 73.4S 51.6E 2085.3 2080.2 64.7S 129.1W 272.8 180.9 181. 7 2100.0 2089.2 76.7S 52.5E 2095.8 2090.8 64.7S 129.0W 273.8 181. 9 182.8 2111.1 2099.7 80.0S 53.4E 2106.4 2101.3 64.7S 128.9W 274.8 183.0 184.0 2122.2 2110.3 83.4S 54.3E 2116.9 2111. 9 64.6S 128.9W 275.9 184.2 185.4 2133.3 2120.8 86.9S 55.3E 2127.2 2122.1 64.6S 128.8W 276.9 185.4 186.8 2144.4 2131.3 90.4S 56.3E 2137.7 2132.6 64.6S 128.7W 277.9 186.8 188.4 2155.6 2141. 7 94.0S 57.3E 2148.2 2143.1 64.6S 128.6W 279.0 188.2 190.0 2166.7 2152.2 97.6S 58.3E 2158.6 2153.6 64.5S 128.5W 280.0 189.7 191. 8 2177.8 2162.6 101.3S 59.3E 2169.1 2164.0 64.5S 128.4W 281.1 191.3 193.7 2188.9 2173.0 105.0S 60.3E 2179.5 2174.4 64.5S 128.3W 282.1 193.0 195.7 2200.0 2183.4 108.8S 61. 4E 2189.8 2184.8 64.5S 128.3W 283.2 194.8 197.8 2211.1 2193.8 112.7S 62.5E 2200.2 2195.1 64.4S 128.2W 284.2 196.7 200.1 2222.2 2204.1 116.6S 63.6E 2210.5 2205.5 64.4S 128.1W 285.2 198.6 202.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska CLEARANCE LISTING Page 17 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 Reference wellpath Object we11path MSS <0-6530'>"KU43-12,Pad 14-6 0.0 100.0 0.0 100.0 O.ON O.ON O.OW O.OW 2.0 100.1 -1. 0 97.1 Horiz Minim TCy1 Rect Coordinates Bearing Dist Dist 150.1S 128.3W 220.5 197.5 197.5 151.0S 128.7W 220.5 198.4 198.4 M.D. T.V.D. Rect Coordinates M.D. T.V.D. All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LI5TING Page 18 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path GM5 <0-6950'>"KBU23X-6,Pad 14-6 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.OW 6.1 0.1 17.85 96.2E 100.5 97.8 97.8 100.0 100.0 O.ON O. OW 106.4 100.4 18.35 95.8E 100.8 97.6* 97.6* 200.0 200.0 O. ON O.OW 206.4 200.4 19.25 95.3E 101.4 97.2* 97.2* 300.0 300.0 O.ON O.OW 306.6 300.5 19.95 94.7E 101.9 96.7* 96.7* 400.0 400.0 O.ON O.OW 406.7 400.6 20.55 93.9E 102.3 96.1* 96.1* 500.0 500.0 O.ON O. OW 506.5 500.5 21.15 93.1E 102.8 95.5* 95.5* 512.5 512.5 O.ON O.OE 519.0 513.0 21.25 93.0E 102.8 95.4* 95.4* 525.0 525.0 O.ON O.lE 531. 5 525.5 21.25 92.9E 102.9 95.2* 95.2* 537.5 537.5 O.lN 0.2E 544.0 538.0 21.35 92.9E 103.0 95.1* 95.1* 550.0 550.0 0.2N 0.4E 556.3 550.3 21.35 92 .8E 103.1 94.9* 94.9* 562.5 562.5 0.3N 0.6E 568.8 562.8 21.45 92.7E 103.2 94.6* 94.6* 575.0 575.0 0.4N 0.9E 581. 3 575.3 21. 45 92.7E 103.4 94.4* 94.4* 587.5 587.5 0.6N 1. 2E 593.8 587.8 21.55 92.6E 103.6 94.0* 94.1* 600.0 600.0 0.8N 1. 6E 606.2 600.2 21. 55 92.6E 103.8 93.7* 93.7* 612.5 612.5 1. ON 2.0E 618.7 612.7 21.65 92.5E 104.0 93.3* 93.4* 625.0 625.0 1.2N 2.5E 631. 2 625.2 21.65 92 .5E 104.2 92.9* 92.9* 637.5 637.4 1. 4N 3.0E 643.7 637.6 21. 75 92.4E 104.5 92.4* 92.5* 650.0 649.9 1. 7N 3.5E 656.2 650.1 21.75 92.4E 104.8 91. 9* 92.0* 662.5 662.4 2.0N 4.1E 668.6 662.6 21.85 92.4E 105.1 91. 4 * 91.5* 675.0 674.9 2.3N 4.8E 681.1 675.1 21.85 92.3E 105.4 90.8* 90.9* 687.5 687.4 2.7N 5.5E 693.6 687.6 21. 95 92.3E 105.8 90.2* 90.3* 700.0 699.8 3.1N 6.3E 706.1 700.1 21.95 92 .2E 106.2 89.5* 89.7* 712.5 712.3 3.5N 7.1E 718.5 712.5 22.05 92 .2E 106.6 88.8* 89.0* 725.0 724.8 3.9N 7.9E 731. 0 725.0 22.05 92 .2E 107.1 88.1* 88.3* 737.5 737.2 4.3N 8.8E 743.5 737.4 22.15 92 .1E 107.6 87.3* 87.5* 750.0 749.7 4.8N 9.8E 756.0 750.0 22.15 92 .1E 108.1 86.5* 86.7* 800.0 799.5 6.7N 13.7E 805.8 799.8 22.25 91.9E 110.3 83.3* 83.5* 850.0 849.3 8.6N 17.6E 855.5 849.4 22.25 91.7E 112.6 80.2* 80.3* 862.5 861.8 9.1N 18.6E 867.9 861. 9 22.25 91.6E 113.2 79.5* 79.6* 875.0 874.2 9.5N 19.5E 880.4 874.4 22.35 91. 6E 113.8 78.8* 78.9* 887.5 886.7 9.9N 20.3E 892.8 886.8 22.35 91.6E 114.3 78.2* 78.3* 900.0 899.1 10.3N 21.2E 905.3 899.3 22.35 91.5E 114.9 77.6* 77.7* 912.5 911.6 10.7N 21. 9E 917.8 911.7 22.35 91. 5E 115.4 77 .0* 77.1* 925.0 924.1 11. ON 22.6E 930.2 924.2 22.45 91. 5E 115.9 76.5* 76.6* 937.5 936.6 11. 4N 23.3E 942.7 936.7 22.45 91. 4E 116.3 76.1* 76.1* 950.0 949.1 11. 7N 23.9E 955.2 949.2 22.45 91. 4E 116.8 75.6* 75.7* 962.5 961. 5 11. 9N 24.5E 967.7 961.7 22.55 91. 4E 117.2 75.2* 75.3* 975.0 974.0 12.2N 25.0E 980.2 974.2 22.55 91. 3E 117.6 74.9* 74.9* 987.5 986.5 12.4N 25.4E 992.7 986.7 22.65 91.3E 118.0 74.5* 74.5* 1000.0 999.0 12.6N 25.9E 1005.2 999.1 22.65 91. 2E 118.3 74.2* 74.2* 1012.5 1011. 5 12.8N 26.2E 1017.6 1011.6 22.75 91.1E 118.6 74.0* 74.0* 1025.0 1024.0 12.9N 26.5E 1030.1 1024.1 22.75 91.1E 118.9 73.7* 73.7* 1037.5 1036.5 13.1N 26.8E 1042.6 1036.6 22.75 91. OE 119.1 73.5* 73.6* 1050.0 1049.0 13.2N 27.0E 1055.0 1049.0 22.85 91. OE 119.3 73.4* 73.4* 1062.5 1061. 5 13.3N 27 .2E 1067.5 1061. 5 22.85 91. OE 119.5 73.3* 73.3* 1075.0 1074.0 13 .3N 27.3E 1080.0 1074.0 22.85 91.0E 119.6 73.2* 73.2* 1087.5 1086.5 13.4N 27.4E 1092.5 1086.5 22.95 91. OE 119.7 73.2* 73.2* 1100.0 1099.0 13.4N 27.4E 1104.9 1098.9 22.95 90.9E 119.7 73.1* 73.1* 1200.0 1199.0 13.4N 27.4E 1205.1 1199.0 23.05 91.0E 119.8 73.3 73.3 1300.0 1299.0 13.4N 27 .4E 1305.8 1299.8 21. 55 91. 2E 118.7 72.7* 72.7* 1400.0 1399.0 13.4N 27.4E 1406.1 1399.9 17.15 92 .2E 115.2 71.6* 71. 6* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#1) (87.00 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1500.0 1511.1 1522.2 1533.3 1544.4 1499.0 1510.1 1521.2 1532.3 1543.4 1555.6 1566.7 1577.8 1588.9 1600.0 1554.5 1565.6 1576.7 1587.8 1598.9 1611.1 1622.2 1633.3 1644.4 1655.6 1610.0 1621.1 1632.2 1643.3 1654.4 1666.7 1677.8 1688.9 1700.0 1711.1 1665.4 1676.5 1687.6 1698.6 1709.7 1722.2 1733.3 1744.4 1755.6 1766.7 1720.7 1731. 7 1742.8 1753.8 1764.8 1777.8 1788.9 1800.0 1811.1 1822.2 1775.8 1786.8 1797.8 1808.7 1819.7 1833.3 1844.4 1855.6 1866.7 1877.8 1830.6 1841. 6 1852.5 1863.4 1874.3 1888.9 1900.0 1911.1 1922.2 1933.3 1885.2 1896.1 1906.9 1917.8 1928.6 1944.4 1955.6 1966.7 1977.8 1988.9 1939.4 1950.2 1961. 0 1971. 8 1982.6 2000.0 2011.1 2022.2 2033.3 2044.4 1993.3 2004.0 2014.7 2025.4 2036.1 2055.6 2046.7 13.4N 13.3N 13.3N 13.1N 12.9N 12.6N 12.3N 11.9N 11. 4N 10.9N 10.3N 9.6N 8.9N 8.1N 7.3N 6.4N 5.4N 4.4N 3.3N 2.1N 0.9N 0.3S 1. 7S 3.1S 4.5S 6.1S 7.6S 9.3S 11.0S 12.7S 14.6S 16.5S 18.4S 20.4S 22.5S 24.6S 26.8S 29.1S 31.4S 33.8S 36.2S 38.7S 41. 3S 43.9S 46.6S 49.3S 52.1S 55.0S 57.9S 60.9S 63.9S Object wellpath 27.4E 27.4E 27.5E 27.5E 27.6E 1506.4 1517.4 1528.6 1539.7 1550.8 M.D. T.V.D. 1499.9 1510.9 1522.0 1533.0 1544.0 1554.9 1565.7 1576.6 1587.4 1597.9 1608.7 1618.9 1629.6 1640.2 1650.3 1660.8 1670.7 1681.1 1690.9 1701.2 1711.5 1721.1 1731.3 1740.6 17 50.7 17 60.8 1769.9 1779.8 1788.8 1798.6 1808.4 1817.1 1826.7 1836.3 1844.6 1854.1 1862.1 1871.4 1880.6 1888.2 1897.3 1906.3 1913.6 1922.4 1931. 3 1938.1 1946.8 1955.4 1961. 8 1970.2 1978.6 e CLEARANCE LISTING Page 19 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 GMS <0-6950'>"KBU23X-6,Pad 14-6 TCy1 Dist Rect Coordinates Bariz Minim Bearing Dist 9.2S 8.0S 6.8S 5.5S 4.1S 2.7S 1.2S 0.4N 2.0N 3.6N 5.3N 7.1N 8.9N 10.8N 12.6N 14.6N 16.5N 18.5N 20.5N 22.7N 24.9N 26.9N 29.2N 31. 3N 33.7N 36.1N 38.3N 40.7N 43.0N 45.5N 48.1N 50.4N 53. IN 55.8N 58.2N 61.0N 63.4N 66.2N 69.1N 71.5N 74.4N 77.4N 79.8N 82.8N 85.8N 88.1N 91. 2N 94.3N 96.6N 99.7N 102.8N 93.9E 94.2E 94.4E 94.7E 94.9E 95.2E 95.5E 95.8E 96.1E 96.4E 96.7E 97.1E 97.5E 97.9E 98.3E 98.8E 99.3E 99.8E 100.3E 100.9E 101.5E 102.1E 102.7E 103.4E 104.1E 104.8E 105.5E 106.2E 106.9E 107.7E 108.5E 109.2E 11 O. OE 11 O. 8E 111. 4E 112.2E 112.9E 113.6E 114.4E 115.0E 115.8E 116.6E 11 7. 2E 118.0E 118.7E 119.3E 120.1E 120.9E 121. 5E 122.3E 123.1E 108.8 107.8 106.7 105.5 104.2 102.8 101. 2 99.6 97.9 96.1 70.2* 70.1* 69.9* 69.7* 69.5* 70.2* 70.1* 69.9* 69.7* 69.5* 27.6E 27.7E 27.9E 28.0E 28.1E 1561. 7 1572.7 1583.7 1594.6 1605.3 69.3* 69.1* 68.9* 68.7* 68.6* 69.3* 69.1* 68.9* 68.8* 68.6* 28.3E 28.5E 28.7E 28.9E 29.1E 1616.2 1626.6 1637.4 1648.2 1658.4 94.1 92.1 90.0 87.8 85.6 68.6* 68.7 68.8 69.1 69.5 68.6* 68.7 68.9 69.1 69.6 29.4E 29.6E 29.9E 30.2E 30.6E 1669.1 1679.3 1689.9 1699.9 1710.5 83.3 81. 0 78.5 76.2 73.7 70.1 70.7 71. 6 72.6 73.8 70.2 70.9 71. 9 73.0 74.3 30.9E 31. 2E 31.6E 32.0E 32.4E 1721. 0 1730.8 1741.3 17 50.9 1761.3 71.3 68.9 66.5 64.3 61. 9 75.1 76.7 78.4 80.3 82.4 75.9 77.6 79.6 81. 9 84.3 32.8E 33.3E 33.7E 34.2E 34.7E 1771.6 1781.0 1791.3 1800.5 1810.7 59.7 57.5 55.4 53.4 51. 4 84.7 87.2 89.9 92.7 95.8 87.0 90.0 93.2 96.7 100.4 35.2E 35.7E 36.3E 36.8E 37.4E 1820.8 1829.9 1839.9 1849.9 1858.6 49.5 47.7 45.9 44.1 42.5 99.0 102.3 105.9 109.6 113.5 104.3 108.5 113.0 117.7 122.7 38.0E 38.6E 39.2E 39.9E 40.5E 1868.4 1876.9 1886.6 1896.3 1904.3 40.9 39.5 38.0 36.6 35.3 117.5 121. 7 126.0 130.5 135.1 128.0 133.5 139.3 145.4 151. 8 41.2E 41. 9E 42.6E 43.4E 44.1E 1913.9 1923.4 1931.1 1940.5 1949.8 34.0 32.7 31. 6 30.5 29.4 139.9 144.8 149.9 155.1 160.4 158.4 165.3 172.6 180.0 187.9 44.9E 45.6E 46.4E 47.2E 48.1E 1957.1 1966.3 1975.5 1982.3 1991.3 28.5 27.5 26.5 25.7 24.8 165.8 171.4 177.1 182.9 188.8 195.9 204.3 213.1 222.1 231.4 48.9E 2000.3 24.0 194.8 241.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska CLEARANCE LISTING Page 20 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 Reference wellpath Object wellpath GMS <0-6950'>"KBU23X-6,Pad 14-6 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing MinIm Dist TCyl Dist All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 21 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object wellpath GMS <0-7375'>"KBU31-7,Pad 14-6 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T. V.D. Rect Coordinates Bearing Dist Dist 800.0 799.5 6.7N 13.7E 808.3 800.3 87.1N 194.8E 66.1 198.2 199.0 850.0 849.3 8.6N 17.6E 857.5 849.5 87.1N 194.7E 66.1 193.7* 194.4* 862.5 861. 8 9.1N 18.6E 870.0 862.0 87.1N 194.6E 66.1 192.6* 193.3* 875.0 874.2 9.5N 19.5E 882.5 874.4 87.1N 194.6E 66.1 191.6* 192.2* 887.5 886.7 9.9N 20.3E 894.9 886.9 87.2N 194.6E 66.1 190.6* 191.1* 900.0 899.1 10.3N 21. 2E 907.0 899.0 87.2N 194.6E 66.1 189.7* 190.2* 912.5 911.6 10.7N 21. 9E 919.5 911.4 87.2N 194.6E 66.1 188.9* 189.3* 925.0 924.1 11. ON 22.6E 931. 7 923.7 87.1N 194.6E 66.1 188.1* 188.4* 937.5 936.6 11.4N 23.3E 944.2 936.2 87.1N 194.7E 66.2 187.4* 187.7* 950.0 949.1 11. 7N 23.9E 956.7 948.7 87.0N 194.8E 66.2 186.7* 187.0* 962.5 961.5 11. 9N 24.5E 969.0 960.9 86.9N 194.8E 66.3 186.1* 186.3* 975.0 974.0 12.2N 25.0E 981.4 973.4 86.8N 194.9E 66.3 185.6* 185.8* 987.5 986.5 12.4N 25.4E 993.9 985.9 86.6N 195.1E 66.4 185.1* 185.2* 1000.0 999.0 12.6N 25.9E 1005.8 997.7 86.4N 195.2E 66.4 184.7* 184.8* 1012.5 1011.5 12.8N 26.2E 1018.3 1010.2 86.2N 195.4E 66.5 184.4* 184.4* 1025.0 1024.0 12.9N 26.5E 1030.7 1022.7 85.9N 195.6E 66.6 184.1* 184.2* 1037.5 1036.5 13.1N 26.8E 1042.1 1034.1 85.7N 195.8E 66.8 184.0* 184.0* 1050.0 1049.0 13.2N 27.0E 1054.6 1046.6 85.3N 196.2E 66.9 183.9* 183.9* 1062.5 1061. 5 13.3N 27.2E 1066.0 1057.9 85.0N 196.5E 67.0 183.9 183.9* 1075.0 1074.0 13.3N 27 .3E 1078.5 1070.4 84.6N 196.9E 67.2 184.0 184.0 1087.5 1086.5 13.4N 27.4E 1091. 0 1082.9 84.1N 197.4E 67.4 184.1 184.2 1100.0 1099.0 13.4N 27.4E 1101.7 1093.6 83.7N 197.8E 67.6 184.4 184.5 1200.0 1199.0 13.4N 27.4E 1194.4 1186.0 80.0N 204.0E 69.3 189.2 189.7 1300.0 1299.0 13.4N 27.4E 1284.3 1275.3 78.0N 213.9E 70.9 198.7 200.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 22 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 Horiz Minim TCy1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 800.0 799.5 6.7N 13.7E 808.3 800.3 87.1N 194.8E 66.1 198.2 199.0 850.0 849.3 8.6N 17.6E 857.5 849.5 87.1N 194.7E 66.1 193.7* 194.4* 862.5 861. 8 9.lN 18.6E 870.0 862.0 87.1N 194.6E 66.1 192.6* 193.3* 875.0 874.2 9.5N 19.5E 882.5 874.4 87.1N 194.6E 66.1 191.6* 192.2* 887.5 886.7 9.9N 20.3E 894.9 886.9 87.2N 194.6E 66.1 190.6* 191.1* 900.0 899.1 10.3N 21. 2E 907.0 899.0 87.2N 194.6E 66.1 189.7* 190.2* 912.5 911.6 10.7N 21.9E 919.5 911. 4 87.2N 194.6E 66.1 188.9* 189.3* 925.0 924.1 11. ON 22.6E 931.7 923.7 87.1N 194.6E 66.1 188.1* 188.4* 937.5 936.6 11.4N 23.3E 944.2 936.2 87.1N 194.7E 66.2 187.4* 187.7* 950.0 949.1 11. 7N 23.9E 956.7 948.7 87.0N 194.8E 66.2 186.7* 187.0* 962.5 961. 5 11. 9N 24.5E 969.0 960.9 86.9N 194.8E 66.3 186.1* 186.3* 975.0 974.0 12.2N 25.0E 981. 4 973 .4 86.8N 194.9E 66.3 185.6* 185.8* 987.5 986.5 12.4N 25.4E 993.9 985.9 86.6N 195.1E 66.4 185.1* 185.2* 1000.0 999.0 12.6N 25.9E 1005.8 997.7 86.4N 195.2E 66.4 184.7* 184.8* 1012.5 1011.5 12.8N 26.2E 1018.3 1010.2 86.2N 195.4E 66.5 184.4* 184.4* 1025.0 1024.0 12.9N 26.5E 1030.7 1022.7 85.9N 195.6E 66.6 184.1* 184.2* 1037.5 1036.5 13.1N 26.8E 1042.1 1034.1 85.7N 195.8E 66.8 184.0* 184.0* 1050.0 1049.0 13.2N 27.0E 1054.6 1046.6 85.3N 196.2E 66.9 183.9* 183.9* 1062.5 1061. 5 13.3N 27.2E 1066.0 1057.9 85.0N 196.5E 67.0 183.9 183.9* 1075.0 1074.0 13.3N 27.3E 1078.5 1070.4 84.6N 196.9E 67.2 184.0 184.0 1087.5 1086.5 13.4N 27.4E 1091. 0 1082.9 84.1N 197.4E 67.4 184.1 184.2 1100.0 1099.0 13.4N 27.4E 1101.7 1093.6 83.7N 197.8E 67.6 184.4 184.5 1200.0 1199.0 13.4N 27.4E 1194.4 1186.0 80.0N 204.0E 69.3 189.2 189.7 1300.0 1299.0 13.4N 27.4E 1284.3 1275.3 78.0N 213 . 9E 70.9 198.7 200.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level; Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - e MARATHON Oil Company CLEARANCE LI5TING Page 23 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference well path Object wellpath PM55 <0 - ????>"KBU24-6,Pad 14-6 Hariz 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.OW 0.3 0.3 8.05 155.3E 92.9 155.5 155.5 100.0 100.0 O.ON O.OW 100.3 100.3 7.95 155.1E 92.9 155.3* 155.3* 200.0 200.0 O.ON O. OW 201.0 201.0 7.65 154.5E 92 .8 154.7* 154.7* 300.0 300.0 O.ON O. OW 301.6 301.6 7.25 153.6E 92.7 153.8* 153.8* 400.0 400.0 O.ON O.OW 402.2 402.2 6.75 152.4E 92.5 152.5* 152.5* 500.0 500.0 O. ON O.OW 503.0 503.0 6.55 150.7E 92.5 150.9* 150.9* 512.5 512.5 O.ON O.OE 515.5 515.5 6.55 150.5E 92.5 150.6* 150.6* 525.0 525.0 O.ON O.lE 528.0 528.0 6.55 150.2E 92.5 150.3* 150.4* 537.5 537.5 O.lN 0.2E 540.5 540.5 6.55 150.0E 92.5 149.9* 150.0* 550.0 550.0 0.2N 0.4E 553.0 553.0 6.55 149.7E 92.6 149.5* 149.6* 562.5 562.5 0.3N 0.6E 565.5 565.4 6.55 149.5E 92.6 149.1* 149.2* 575.0 575.0 0.4N 0.9E 578.0 577.9 6.55 149.2E 92.7 148.5* 148.7* 587.5 587.5 0.6N 1. 2E 591.0 590.9 6.65 148.9E 92.8 148.0* 148.1* 600.0 600.0 0.8N 1. 6E 603.5 603.4 6.65 148.7E 92.9 147.3* 147.5* 612.5 612.5 1. ON 2.0E 615.9 615.9 6.65 148.4E 93.0 146.6* 146.9* 625.0 625.0 1.2N 2.5E 628.4 628.4 6.65 148.1E 93.1 145.9* 146.2* 637.5 637.4 1.4N 3.0E 640.9 640.8 6.65 147.8E 93.2 145.1* 145.4* 650.0 649.9 1. 7N 3.5E 653.4 653.3 6.65 147.5E 93.3 144.2* 144.6* 662.5 662.4 2.0N 4.1E 666.4 666.3 6.75 147.2E 93.5 143.3* 143.7* 675.0 674.9 2.3N 4.8E 678.9 678.8 6.75 146.8E 93.6 142.4* 142.8* 687.5 687.4 2.7N 5.5E 691.3 691.2 6.75 146.5E 93.8 141.4* 141. 9* 700.0 699.8 3.1N 6.3E 703.8 703.7 6.75 146.2E 94.0 140.3* 140.8* 712.5 712.3 3.5N 7.1E 716.2 716.1 6.75 145.8E 94.2 139.2* 139.8* 725.0 724.8 3.9N 7.9E 728.6 728.6 6.75 145.5E 94.4 138.0* 138.6* 737.5 737.2 4.3N 8.8E 741.1 741.0 6.65 145.1E 94.6 136.8* 137.5* 750.0 749.7 4.8N 9.8E 754.1 754.0 6.65 144.7E 94.8 135.5* 136.2* 800.0 799.5 6.7N 13.7E 803.7 803.6 6.55 143.2E 95.8 130.2* 131. 0* 850.0 849.3 8.6N 17.6E 853.4 853.2 6.45 141. 6E 96.9 124.9* 125.6* 862.5 861. 8 9.1N 18.6E 865.8 865.6 6.45 141. 2E 97.2 123.7* 124.3* 875.0 874.2 9.5N 19.5E 877.6 877.5 6.35 140.9E 97.4 122.5* 123.0* 887.5 886.7 9.9N 20.3E 890.1 889.9 6.35 140.5E 97.7 121. 3* 121.8* 900.0 899.1 10.3N 21. 2E 902.5 902.4 6.25 140.2E 97.9 120.2* 120.7* 912.5 911.6 10.7N 21. 9E 914.4 914.3 6.25 139.9E 98.1 119.2* 119.6* 925.0 924.1 11. ON 22.6E 926.9 926.7 6.15 13 9 . 6E 98.3 118.3* 118.6* 937.5 936.6 11.4N 23.3E 939.3 939.2 6.15 13 9. 4E 98.5 117.4* 117.7* 950.0 949.1 11. 7N 23.9E 951.8 951.6 6.05 13 9 .1E 98.7 116.6* 116.8* 962.5 961. 5 11. 9N 24.5E 964.3 964.1 6.05 138.9E 98.9 115.8* 116.0* 975.0 974.0 12.2N 25.0E 976.8 976.6 5.95 138.6E 99.0 115.1* 115.3* 987.5 986.5 12.4N 25.4E 989.2 989.0 5.85 13 8. 4E 99.2 114.4* 114.6* 1000.0 999.0 12.6N 25.9E 1001. 7 1001. 5 5.85 138.1E 99.3 113.8* 113.9* 1012.5 1011.5 12.8N 26.2E 1014.2 1014.0 5.75 137.8E 99.4 113.2* 113.3* 1025.0 1024.0 12.9N 26.5E 1026.7 1026.5 5.75 137.6E 99.5 112.6* 112.7* 1037.5 1036.5 13 .1N 26.8E 1039.2 1039.0 5.65 13 7. 3E 99.6 112.0* 112.1* 1050.0 1049.0 13.2N 27.0E 1051.7 1051. 5 5.55 13 7. OE 99.7 111.6* 111. 6* 1062.5 1061.5 13.3N 27.2E 1064.7 1064.5 5.55 13 6. 7E 99.7 111.1* 111. 2* 1075.0 1074.0 13.3N 27 .3E 1077.2 1076.9 5.45 13 6. 4E 99.8 110.7* 110.7* 1087.5 1086.5 13.4N 27.4E 1089.7 1089.4 5.45 13 6. OE 99.8 110.3* 110.3* 1100.0 1099.0 13.4N 27.4E 1102.1 1101.9 5.35 13 5. 7E 99.8 109.9* 110.0* 1200.0 1199.0 13.4N 27.4E 1202.6 1202.3 4.95 132.9E 99.8 107.1* 107.1* 1300.0 1299.0 13.4N 27.4E 1302.4 1302.1 4.55 129.8E 99.9 103.9* 104.0* 1400.0 1399.0 13.4N 27.4E 1400.2 13 99.9 4.05 127.9E 99.8 102.0* 102.0* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#1 ) (87.00 Ft above mean sea level: Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1500.0 1511.1 1522.2 1533.3 1544.4 1499.0 1510.1 1521.2 1532.3 1543.4 1555.6 1566.7 1577.8 1588.9 1600.0 1554.5 1565.6 1576.7 1587.8 1598.9 1611.1 1622.2 1633.3 1644.4 1655.6 1610.0 1621.1 1632.2 1643.3 1654.4 1666.7 1677.8 1688.9 1700.0 1711.1 1665.4 1676.5 1687.6 1698.6 1709.7 1722.2 1733.3 1744.4 17 55.6 1766.7 1720.7 1731.7 1742.8 1753.8 17 64.8 1777.8 1788.9 1800.0 1811.1 1822.2 1775.8 1786.8 1797.8 1808.7 1819.7 1833.3 1844.4 1855.6 1866.7 1877.8 1830.6 1841. 6 1852.5 1863.4 1874.3 1888.9 1900.0 1911.1 1922.2 1933.3 1885.2 1896.1 1906.9 1917.8 1928.6 1944.4 1955.6 1966.7 1977.8 1988.9 1939.4 1950.2 1961.0 1971.8 1982.6 2000.0 2011.1 2022.2 2033.3 2044.4 1993.3 2004.0 2014.7 2025.4 2036.1 2055.6 2046.7 13.4N 13.3N 13.3N 13.1N 12.9N 12.6N 12.3N 11. 9N 11.4N 10.9N 10.3N 9.6N 8.9N 8.1N 7.3N 6.4N 5.4N 4.4N 3.3N 2.1N 0.9N 0.3S 1. 7S 3.1S 4.5S 6.1S 7.6S 9.3S 11.0S 12.7S 14.6S 16.5S 18.4S 20.4S 22.5S 24.6S 26.8S 29.1S 31.4S 33.8S 36.2S 38.7S 41.3S 43.9S 46.6S 49.3S 52.1S 55.0S 57.9S 60.9S 63.9S 27.4E 27.4E 27.5E 27.5E 27.6E 27.6E 27.7E 27.9E 28.0E 28.1E e CLEARANCE LISTING Page 24 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 Object we11path M.D. T.V.D. PMS5 <0 - ????>"KBU24-6,Pad 14-6 TCy1 Dist 1499.2 1509.9 1521.0 1532.1 1542.8 1553.9 1565.0 1575.6 1586.7 1597.8 28.3E 28.5E 28.7E 28.9E 29.1E 1608.4 1619.5 1630.6 1641.1 1652.2 1498.8 1509.5 1520.6 1531.7 1542.4 1553.5 1564.6 1575.3 1586.4 1597.5 1608.1 1619.2 1630.2 1640.7 1651.8 1662.8 1673.3 1684.3 1695.3 1705.6 1716.6 1727.6 1737.7 1748.6 1759.6 1769.6 1780.5 17 91. 4 1801.4 1812.3 1823.1 1833.2 1844.0 1854.8 1864.9 1875.6 1886.4 1896.2 1906.9 1917.6 1927.2 1937.8 1948.4 1957.9 1968.5 1979.0 1988.3 1998.8 2009.3 2018.5 2028.9 Rect Coordinates 3.35 3.25 3.25 3.1S 3.0S 3.05 2.95 2.7S 2.6S 2.4S 2.35 2.15 1. 9S 1. 6S 1.4S 1.1S 0.9S 0.6S 0.3S O.OS 0.3N 0.6N 0.9N 1. 2N 1. 6N 1. 9N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 5.2N 5.6N 6. ON 6.4N 6.8N 7.2N 7.6N 8.0N 8.5N 8.9N 9.3N 9.8N 10.2N 10.6N 11.1N 11.6N 12.0N 12.5N 127.6E 127 . 7E 127.7E 127.8E 127.9E 128.0E 128.2E 128.3E 128.5E 128.7E 128.9E 129.1E 129.3E 129.6E 129.9E 13 O. 2E 13 O. 5E 130.8E 131.2E 131.6E 132.0E 132.5E 132.9E 133.4E 134.0E 13 4. 5E 135.1E 135.8E 136.4E 137.1E 137.8E 138.5E 139.3E 140.1E 140.9E 141.7E 142.6E 143.4E 144.4E 14 5. 4E 146.3E 147.3E 148.4E 149.4E 150.5E 151.7E 152.8E 154.0E 155.3E 156.4E 157.8E Horiz Bearing Min'm Dist 99.5 99.4 99.3 99.2 99.0 101.6* 101.6 101.6 101.6 101. 6* 29.4E 29.6E 29.9E 30.2E 30.6E 1663.2 1673.7 1684.7 1695.7 1706.0 101.6* 101.6 101.6 101.6 101. 6* 98.8 98.6 98.3 97.9 97.5 101.6* 101.6* 101.5* 101.5* 101.4* 101.6* 101.6* 101. 5* 101. 5* 101.4* 30.9E 31. 2E 31.6E 32.0E 32.4E 1717.0 1728.0 1738.1 1749.1 1760.1 97.1 96.6 96.1 95.5 94.9 101. 4 * 101. 3* 101. 3* 101. 2* 101.2* 101. 4 * 101.3* 101. 3* 101.2* 101.2* 32.8E 33.3E 33.7E 34.2E 34.7E 1770.1 1781.0 17 91. 9 1802.0 1812.9 94.2 93.6 92.8 92.0 91. 2 101.1* 101.1* 101.1* 101.1 101.1 101.1* 101.1* 101.1* 101.1 101.1 35.2E 35.7E 36.3E 36.8E 37.4E 1823.8 1833.9 1844.8 1855.6 1865.7 90.4 89.5 88.6 87.6 86.6 101. 2 101.3 101.5 101.7 101.9 101. 2 101.3 101. 5 101.7 101. 9 38.0E 38.6E 39.2E 39.9E 40.5E 1876.5 1887.3 1897.1 1907.9 1918.6 85.5 84.4 83.3 82.2 81. 0 102.2 102.5 102.9 103.4 103.9 102.2 102.6 103.0 103.5 104.1 41.2E 41.9E 42.6E 43.4E 44.1E 1928.2 1938.9 1949.6 1959.2 1969.8 79.8 78.6 77 .3 76.1 74.8 104.7 105.4 106.2 107.1 108.0 44.9E 45.6E 46.4E 47.2E 48.1E 1980.4 1989.8 2000.4 2011.0 2020.2 104.5 105.2 105.9 106.7 107.6 73.6 72 .3 71. 0 69.7 68.4 109.0 110.2 111.4 112.7 114.2 48.9E 2030.7 108.6 109.6 110.7 111.9 113.2 67.2 65.9 64.6 63.3 62.1 115.7 117.4 119.2 121.1 123.1 114.6 116.1 117.7 119.4 121. 2 60.9 59.6 58.4 57.3 56.1 125.3 127.6 130.0 132.5 135.2 123.1 125.1 127.2 129.5 131. 8 54.9 134.2 138.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LISTING Page 25 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path PMSS <0 - ????>"KBU24-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2066.7 2057.4 67.0S 49.8E 2041.2 2039.3 13. ON 159.1E 53.8 136.7 141.0 2077.8 2068.0 70.2S 50.7E 2050.3 2048.3 13.5N 160.3E 52.7 139.3 144.0 2088.9 2078.6 73.4S 51.6E 2060.7 2058.6 14.0N 161. 7E 51.6 142.1 147.2 2100.0 2089.2 76.7S 52.5E 2071.2 2068.9 14.6N 163.2E 50.5 144.9 150.6 2111.1 2099.7 80.0S 53.4E 2080.4 2078.1 15.1N 164.5E 49.5 147.8 154.0 2122.2 2110.3 83.4S 54.3E 2090.8 2088.3 15.6N 166.0E 48.4 150.9 157.5 2133.3 2120.8 86.9S 55.3E 2101. 1 2098.5 16.2N 167.6E 47.5 154.0 161.2 2144.4 2131. 3 90.4S 56.3E 2110.6 2107.9 16.6N 169.0E 46.5 157.2 165.0 2155.6 2141. 7 94.0S 57.3E 2120.9 2118.0 17.2N 170.6E 45.6 160.5 168.9 2166.7 2152.2 97.6S 58.3E 2131. 2 2128.2 17.7N 172 . 2E 44.7 163.8 172.9 2177.8 2162.6 101. 3S 59.3E 2140.6 2137.5 18.2N 173.7E 43.8 167.3 177.0 2188.9 2173.0 105.0S 60.3E 2150.9 2147.6 18.7N 175.4E 42.9 170.8 181.3 2200.0 2183.4 108.8S 61.4E 2161.1 2157.6 19.2N 177.1E 42.1 174.4 185.6 2211.1 2193.8 112.7 S 62.5E 2170.3 2166.7 19.6N 178.6E 41.3 178.1 190.1 2222.2 2204.1 116.6S 63.6E 2180.5 2176.7 20.1N 180.4E 40.5 181.9 194.7 2233.3 2214.4 120.6S 64.7E 2190.7 2186.7 20.6N 182.2E 39.8 185.8 199.4 2244.4 2224.7 124.7S 65.8E 2200.8 2196.7 21.1N 18 4. OE 39.0 189.7 204.2 2255.6 2235.0 128.7S 66.9E 2209.8 2205.5 21.5N 185.6E 38.3 193.7 209.2 2266.7 2245.2 132.9S 68.1E 2219.9 2215.4 22.0N 187.4E 37.6 197.8 214 .3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 512.5 525.0 537.5 550.0 500.0 512.5 525.0 537.5 550.0 562.5 575.0 587.5 600.0 612.5 562.5 575.0 587.5 600.0 612.5 625.0 637.5 650.0 662.5 675.0 625.0 637.4 649.9 662.4 674.9 687.5 700.0 712.5 725.0 737.5 687.4 699.8 712.3 724.8 737.2 750.0 800.0 850.0 862.5 875.0 749.7 799.5 849.3 861. 8 874.2 887.5 900.0 912.5 925.0 937.5 886.7 899.1 911.6 924.1 936.6 950.0 962.5 975.0 987.5 1000.0 949.1 961. 5 974.0 986.5 999.0 1012.5 1025.0 1037.5 1050.0 1062.5 1011. 5 1024.0 1036.5 1049.0 1061.5 1075.0 1087.5 1100.0 1200.0 1300.0 1074.0 1086.5 1099.0 1199.0 1299.0 1400.0 1399.0 O.ON O.ON O.ON O. ON O. ON O.ON O.ON O.ON O.lN 0.2N 0.3N 0.4N 0.6N 0.8N 1. ON 1.2N 1. 4N 1. 7N 2.0N 2.3N 2.7N 3.1N 3.5N 3.9N 4.3N 4.8N 6.7N 8.6N 9.1N 9.5N 9.9N 10.3N 10.7N 11. ON 11. 4N 11.7N 11.9N 12.2N 12.4N 12.6N 12.8N 12.9N 13. IN 13.2N 13.3N 13.3N 13.4N 13.4N 13.4N 13.4N 13.4N 9.8E 13.7E 17.6E 18.6E 19.5E 20.3E 21. 2E 21.9E 22.6E 23.3E 23.9E 24.5E 25.0E 25.4E 25.9E 26.2E 26.5E 26.8E 27.0E 27 .2E 27.3E 27.4E 27.4E 27 .4E 27.4E 27.4E Object wellpath O.OW O.OW O.OW O.OW O.OW 0.0 97.5 197.1 297.9 397.9 M.D. T.V.D. 2.0 99.5 199.1 299.9 399.9 500.1 512.6 525.1 537.7 550.2 562.7 575.2 587.7 600.8 613.2 626.9 640.6 654.6 667.0 679.5 693.7 706.1 720.4 732.8 746.5 758.9 809.7 860.0 872.4 884.7 897.7 910.0 923.0 935.4 947.7 960.5 972.8 985.7 998.0 1010.8 1023.1 1035.3 1048.1 1060.3 1072.9 1085.1 1097.7 1109.8 1207.0 1302.3 1397.6 e CLEARANCE LISTING Page 26 Your ref KED 23-7 Version#l Last revised: 17-Nov-2003 MSS <0-4453'>"KU21-7,Pad 14-6 Rect Coordinates Horiz MinIm Bearing Dist 40.6N 40.6N 40.4N 40.1N 40.0N 39.7N 39.6N 39.6N 39.5N 39.4N 39.3N 39.1N 38.9N 38.5N 38.2N 37.7N 37.1N 36.4N 35.7N 35.0N 34.2N 33.5N 32.7N 31. 9N 31.1N 30.3N 27.1N 23.8N 23.0N 22.2N 21.4N 20.6N 19.8N 19.1N 18.4N 17.7N 17.0N 16.2N 15.5N 14.6N 13.7N 12.8N 11.8N 10.8N 9.6N 8.5N 7.2N 6. ON 4.8S 17.5S 30.4S 91. OW 91. 3W 92.1W 93.0W 93.1W 93.3W 93.3W 93.3W 93.3W 93.3W 93.4W 93.4W 93.5W 93.6W 93.6W 93.6W 93.4W 93.2W 92.9W 92.6W 92. OW 91. 4W 90.6W 89.8W 88.9W 87.9W 83.6W 78.9W 77.7W 76.4W 75.1W 73.7W 72 .3W 70.9W 69.4W 67.9W 66.4W 64.8W 63.3W 61.6W 60.0W 58.3W 56.6W 54.9W 53.0W 51. 3W 49.4W 47.6W 31.5W 14.6W 2.5E TCyl Dist 294.1 294.0 293.7 293.4 293.3 99.7 99.9 100.6 101. 3 101.4 O.OW O.OE O.lE 0.2E 0.4E 498.1 510.6 523.1 535.7 548.2 99.7 99.9 100.6 101.3 101. 4 293.0 293.0 292.9 292.9 292.7 101.4 101.4 101.4 101. 5 101.6 101.4 101.4 101. 4 101. 5 101.6 0.6E 0.9E 1.2E 1. 6E 2.0E 560.7 573.2 585.7 598.8 611.3 292.5 292 .3 292.0 291. 7 291.3 101.7 101.9 102.1 102.4 102.6 2.5E 3.0E 3.5E 4.1E 4.8E 625.0 638.7 652.7 665.1 677.6 101.7 101.9 102.1 102.4 102.6 290.8 290.3 289.7 289.1 288.6 102.7 102.8 102.9 102.9* 102.8* 102.7 102.8 102.9 102.9* 102.8* 5.5E 6.3E 7.1E 7.9E 8.8E 691.9 704.3 718.6 731.1 744.8 287.9 287.3 286.6 286.0 285.3 102.7* 102.5* 102.3* 102.0* 101.7* 102.7* 102.5* 102.3* 102.1* 101.8* 757.3 808.4 859.0 871. 5 883.9 897.0 909.4 922.5 934.9 947.4 960.3 972.8 985.7 998.1 1011.1 1023.5 1035.9 1048.8 1061.2 1074.0 1086.3 1099.1 1111.4 1210.5 1308.1 1405.9 284.6 281. 9 279.0 278.2 277.5 101.4* 100.0* 98.3* 97.9* 97.4* 101.4* 100.0* 98.3* 97.8* 97.3* 276.8 276.2 275.5 274.9 274.3 96.7* 96.1* 95.3* 94.5* 93.6* 96.8* 96.2* 95.5* 94.7* 93.9* 273.7 273.2 272.6 272.0 271. 3 93.0* 92.0* 91.0* 89.9* 88.7* 92.7* 91.7* 90.6* 89.5* 88.3* 270.6 269.9 269.1 268.3 267.4 87.5* 86.2* 84.8* 83.3* 81. 8* 87.0* 85.6* 84.2* 82.7* 81.1* 266.5 265.4 264.4 252.8 233.7 79.5* 77.9* 76.1* 62.2* 52.3* 80.2* 78.6* 76.9* 62.7* 52.4* 209.7 50.5* 50.5* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LI5TING Page 27 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path M55 <0-4453'>"KU21-7,Pad 14-6 Horiz MinIm TCy1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1500.0 1499.0 13.4N 27.4E 1504.0 1493.5 42.75 19.6E 187.9 56.9 57.2 1511.1 1510.1 13.3N 27.4E 1514.9 1504.1 44.05 21.6E 185.9 58.0 58.3 1522.2 1521.2 13.3N 27 .5E 1525.7 1514.7 45.35 23.5E 183.9 59.1 59.4 1533.3 1532.3 13 .1N 27.5E 1536.6 1525.3 46.65 25.4E 182.0 60.2 60.5 1544.4 1543.4 12.9N 27.6E 1547.5 1536.0 47.95 27.3E 180.3 61.3 61.6 1555.6 1554.5 12.6N 27.6E 1558.4 1546.6 49.25 29.2E 178 .5 62.3 62.7 1566.7 1565.6 12.3N 27.7E 1569.3 1557.3 50.55 31.1E 176.9 63.4 63.7 1577.8 1576.7 l1.9N 27.9E 1580.2 1567.9 51.85 33.0E 175.3 64.5 64.8 1588.9 1587.8 11.4N 28.0E 1591.2 1578.6 53.25 35.0E 173.8 65.6 65.9 1600.0 1598.9 10.9N 28.1E 1602.1 1589.3 54.55 36.9E 172.4 66.6 67.0 1611. 1 1610.0 10.3N 28.3E 1613.0 1600.0 55.85 38.8E 171.0 67.7 68.0 1622.2 1621. 1 9.6N 28.5E 1623.7 1610.4 57.25 40.7E 169.6 68.7 69.0 1633.3 1632.2 8.9N 28.7E 1634.6 1621.1 58.55 42.6E 168.3 69.7 70.0 1644.4 1643.3 8.1N 28.9E 1645.6 1631. 8 59.95 44.5E 167.1 70.7 71.0 1655.6 1654.4 7.3N 29.1E 1656.6 1642.5 61.25 46.4E 165.8 71.7 71.9 1666.7 1665.4 6.4N 29.4E 1667.5 1653.2 62.65 48.4E 164.6 72.6 72.9 1677.8 1676.5 5.4N 29.6E 1678.5 1663.9 64.05 50.3E 163.4 73.5 73.7 1688.9 1687.6 4.4N 29.9E 1689.3 1674.5 65.45 52.2E 162.3 74.4 74.6 1700.0 1698.6 3.3N 30.2E 1700.3 1685.2 66.85 54.1E 161.2 75.2 75.4 1711. 1 1709.7 2.1N 30.6E 1711.3 1695.9 68.25 56.0E 160.1 76.0 76.2 1722.2 1720.7 0.9N 30.9E 1722.3 1706.6 69.65 58.0E 159.0 76.8 77.0 1733.3 1731.7 0.35 31.2E 1733.3 1717.4 71.05 59.9E 157.9 77.6 77.7 1744.4 1742.8 1. 75 31.6E 1744.2 1728.1 72.35 61.9E 156.8 78.3 78.4 1755.6 1753.8 3.15 32.0E 1755.2 1738.8 73.75 63.8E 155.8 78.9 79.1 1766.7 1764.8 4.55 32.4E 1766.2 1749.5 75.15 65.7E 154.7 79.6 79.7 1777.8 1775.8 6.15 32.8E 1777.2 1760.2 76.55 67.7E 153.7 80.2 80.3 1788.9 1786.8 7.65 33.3E 1788.2 1770.9 77.95 69.7E 152.6 80.7 80.8 1800.0 17 97.8 9.35 33.7E 1799.2 1781.7 79.35 71.6E 151.6 81.2 81.3 1811. 1 1808.7 11.05 34.2E 1810.2 17 92.4 80.75 73.6E 150.5 81.7 81.8 1822.2 1819.7 12.75 34.7E 1821.2 1803.2 82.15 75.6E 149.5 82.2 82.3 1833.3 1830.6 14.65 35.2E 1832.2 1813.9 83.55 77.6E 148.4 82.6 82.7 1844.4 1841. 6 16.55 35.7E 1843.3 1824.7 84.95 79.6E 147.3 83.0 83.1 1855.6 1852.5 18.45 36.3E 1854.3 1835.5 86.35 81.6E 146.3 83.4 83.4 1866.7 1863.4 20.45 36.8E 1865.3 1846.2 87.75 83.5E 145.2 83.7 83.7 1877.8 1874.3 22.55 37.4E 1876.3 1856.9 89.15 85.5E 144.1 84.0 84.0 1888.9 1885.2 24.65 38.0E 1887.3 1867.7 90.45 87.5E 143.1 84.2 84.2 1900.0 1896.1 26.85 38.6E 1898.3 1878.4 91.85 89.4E 142.0 84.4 84.4 1911.1 1906.9 29.15 39.2E 1909.3 1889.1 93.25 91.4E 140.9 84.5 84.5 1922.2 1917.8 31.45 39.9E 1920.6 1900.2 94.65 93.4E 139.7 84.7 84.7 1933.3 1928.6 33.85 40.5E 1931.6 1910.9 96.05 95.4E 138.6 84.8 84.8 1944.4 1939.4 36.25 41.2E 1942.6 1921. 7 97.35 97.3E 137.4 84.8 84.8 1955.6 1950.2 38.75 41.9E 1953.6 1932.4 98.75 99.2E 136.3 84.8 84.8 1966.7 1961.0 41.35 42.6E 1964.6 1943.1 100.05 101.1E 135.1 84.8* 84.8* 1977.8 1971.8 43.95 43.4E 1975.5 1953.8 101.35 103.1E 133.9 84.8* 84.8* 1988.9 1982.6 46.65 44.1E 1986.6 1964.6 102.75 105.0E 132.7 84.7* 84.7* 2000.0 1993.3 49.35 44.9E 1997.6 1975.4 104.05 106.9E 131. 4 84.6* 84.6* 2011.1 2004.0 52.15 45.6E 2008.5 1986.1 105.45 108.8E 130.1 84.5* 84.6* 2022.2 2014.7 55.05 46.4E 2019.5 1996.8 106.85 11 0 . 7E 128.9 84.4* 84.4* 2033.3 2025.4 57.95 47.2E 2030.4 2007.5 108.15 112.6E 127.6 84.3* 84.3* 2044.4 2036.1 60.95 48.1E 2041. 3 2018.1 109.55 114.4E 126.2 84.2* 84.2* 2055.6 2046.7 63.95 48.9E 2052.2 2028.8 110.95 116.3E 124.9 84.1* 84.1* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#l) (87.00 Ft above mean sea level: Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - MARATHON Oil Company Pad 14-6,KBU23-7 Kenai Gas Field,Kenai peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 2066.7 2077.8 2088.9 2100.0 2111.1 2057.4 2068.0 2078.6 2089.2 2099.7 2122.2 2133.3 2144.4 2155.6 2166.7 2110.3 2120.8 2131.3 2141. 7 2152.2 2177.8 2188.9 2200.0 2211.1 2222.2 2162.6 2173.0 2183.4 2193.8 2204.1 2233.3 2244.4 2255.6 2266.7 2277.8 2214.4 2224.7 2235.0 2245.2 2255.4 2288.9 2300.0 2311.1 2322.2 2333.3 2265.6 227 5.8 2285.9 2296.0 2306.1 2344.4 2355.6 2366.7 2377.8 2388.9 2316.2 2326.2 2336.2 2346.2 2356.1 2400.0 2411.1 2422.2 2433.3 2444.4 2366.0 2375.9 2385.8 2395.6 2405.4 2455.6 2466.7 2477.8 2488.9 2500.0 2415.2 2424.9 2434.6 2444.3 2453.9 2511.1 2522.2 2533.3 2544.4 2555.6 2463.5 2473.1 2482.6 2492.1 2501.6 2566.7 2577.8 2588.9 2600.0 2611.1 2511.1 2520.5 2529.8 2539.2 2548.5 2622.2 2557.7 67.05 70.25 73.45 76.75 80.05 83.45 86.95 90.45 94.05 97.65 101.35 105.05 108.85 112.75 116.65 120.65 124.75 128.75 132.95 137.15 141. 45 145.75 150.15 154.55 159.05 163.65 168.25 172.95 177.65 182.35 187.25 192.15 197.05 202.05 207.15 212.25 217.35 222.65 227.85 233.15 238.55 244.05 249.45 255.05 260.65 266.25 271. 95 277.75 283.55 289.35 295.25 97.4E 99.0E 100.5E 102.0E 103.6E 105.1E 106.7E 108.3E 109.9E 111.6E 113.2E Object we11path 49.8E 50.7E 51.6E 52.5E 53.4E 2063.2 2074.1 2085.0 2095.9 2106.8 M.D. T.V.D. 2039.4 2050.1 2060.8 2071.4 2082.1 2092.7 2103.4 2114.0 2124.7 2135.3 2145.9 2156.5 2167.1 2177.6 2188.2 2198.7 2209.3 2219.8 2230.3 2240.8 2251.3 2261. 7 2272.2 2282.6 2293.0 2303.3 2313.7 2324.1 2334.4 2344.7 2355.0 2365.3 2375.6 2385.8 2396 .1 2406.3 2416.5 2426.6 2436.8 2447.3 2457.4 2467.5 2477.6 2488.5 2498.6 2508.6 2518.6 2528.6 2539.6 2549.5 2559.5 e CLEARANCE LI5TING Page 28 Your ref KBU 23-7 Version#l Last revised: 17-Nov-2003 M55 <0-4453'>"KU21-7,Pad 14-6 Rect Coordinates Horiz Minim Bearing Dist 112.35 113.75 115.25 116.65 118.15 119.65 121.15 122.65 124.15 125.65 127 .15 128.65 130.15 131. 55 133.05 134.55 135.95 137.45 138.85 140.35 141. 75 143.15 144.55 145.95 147.35 148.75 150.15 151.55 152.95 154.25 155.65 157.05 158.45 159.75 161.15 162.55 163.85 165.25 166.55 167.95 16 9.35 170.75 172.15 173.65 17 5.05 176.45 177.85 17 9.35 180.95 182.35 183.85 118.2E 120.0E 121.9E 123.7E 125.5E 127 . 4E 129.2E 131. OE 132.8E 134.6E 13 6. 4E 13 8. 2E 140.0E 141.8E 143.6E 145.4E 147.2E 149.0E 150.8E 152.6E 154.4E 156.2E 157.9E 159.7E 161. 5E 163.3E 165.0E 166.8E 168.6E 17 0 . 4E 172 . IE 173.9E 17 5 . 6E 177 . 4E 179.1E 180.9E 182.6E 184.4E 186.1E 187.9E 189.6E 191. 3E 193.0E 194.8E 196.5E 198.1E 199.8E 201.4E 203.2E 204.8E 206.4E 123.5 122.1 120.7 119.3 117.8 116.3 114.8 113.3 111.7 110.1 108.5 106.8 105.1 103.4 101.6 TCy1 Dist 84.0* 83.8* 83.7* 83.6* 83.5* 84.0* 83.8* 83.7* 83.6* 83.5* 54.3E 55.3E 56.3E 57.3E 58.3E 2117.7 2128.6 2139.5 2150.4 2161. 3 83.4* 83.3* 83.2* 83.1* 83.0* 83.4* 83.3* 83.2* 83.1* 83.0* 59.3E 60.3E 61. 4E 62.5E 63.6E 2172.2 2183.0 2193.9 2204.7 2215.5 83.0* 83.0 83.1 83.1 83.2 83.0* 83.0 83.1 83.1 83.2 64.7E 65.8E 66.9E 68.1E 69.3E 2226.3 2237.1 2247.8 2258.6 2269.3 99.7 97.9 96.0 94.1 92.2 83.4 83.6 83.9 84.2 84.7 83.4 83.6 83.9 84.3 84.7 70.4E 71.6E 72.9E 74.1E 75.3E 2280.0 2290.8 2301. 4 2312.1 2322.7 90.2 88.2 86.3 84.3 82.3 85.1 85.7 86.4 87.1 87.9 85.2 85.8 86.5 87.3 88.2 76.6E 77.9E 79.2E 80.5E 81. 8E 2333.4 2344.0 2354.6 2365.2 2375.7 80.3 78.3 76.3 74.3 72.4 88.9 89.9 91. 0 92.2 93.6 89.2 90.3 91. 6 92.9 94.4 83.2E 84.5E 85.9E 87.3E 88.7E 2386.3 2396.8 2407.3 2417.8 2428.2 70.5 68.6 66.7 64.9 63.1 95.0 96.6 98.2 100.0 101.9 96.0 97.7 99.5 101.5 103.6 90.1E 91. 6E 93.0E 94.5E 96.0E 2438.7 2449.1 2459.5 2469.9 2480.7 61.3 59.6 57.9 56.2 54.7 103.9 106.0 108.2 110.5 112.9 105.8 108.2 110.7 113.3 116.0 2491.0 2501.4 2511.7 2522.9 2533.1 2543.4 2553.6 2563.9 2575.1 2585.3 2595.4 53.1 51. 6 50.1 48.7 47.4 115.4 118.0 120.7 123.5 126.4 118.8 121.8 124.8 128.0 131. 2 46.0 44.7 43.4 42.3 41.1 129.3 132.3 135.5 138.7 141.9 134.6 138.1 141. 6 145.3 149.1 39.9 145.3 153.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (G1acier#1) (87.00 Ft above mean sea level: Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company CLEARANCE LI5TING Page 29 Pad 14-6,KBU23-7 Your ref KBU 23-7 Version#l Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 17-Nov-2003 Reference wellpath Object we11path M55 <0-4453'>"KU21-7,Pad 14-6 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2633.3 2567.0 301.25 114.9E 2605.6 2569.4 185.25 207.9E 38.7 148.7 157.2 2644.4 2576.2 307.25 116.5E 2615.7 2579.2 186.75 209.5E 37.6 152.2 161.5 2655.6 2585.3 313.35 118.2E 2625.9 2589.2 188.25 211.0E 36.6 155.8 165.9 2666.7 2594.4 319.45 119.9E 2636.0 2599.1 189.75 212.6E 35.5 159.5 170.5 2677 . 8 2603.5 325.65 121.6E 2646.0 2608.9 191.25 214.2E 34.6 163.3 175.2 2688.9 2612.6 331.85 123.4E 2655.1 2617.7 192.55 215.7E 33.5 167.2 180.1 2700.0 2621. 6 338.15 125.1E 2665.1 2627.5 194.05 217 . 3E 32.6 171.2 185.1 2711.1 2630.5 344.45 126.9E 2675.0 2637.2 195.45 219.0E 31.7 175.2 190.3 2722.2 2639.5 350.75 128.6E 2684.0 2646.0 196.75 220.5E 30.8 179.4 195.6 27 33.3 2648.4 357.25 130.4E 2693.9 2655.6 198.25 222.2E 30.0 183.7 201.1 2744.4 2657.2 363.65 132.2E 2703.8 2665.2 199.65 223.9E 29.2 188.1 206.7 2755.6 2666.0 370.15 134.0E 2712.9 2674.1 200.95 225.5E 28.4 192.6 212.5 27 66.7 2674.8 376.75 135.9E 2722.7 2683.6 202.35 227.3E 27.7 197.1 218.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KBU 23-7 and TVD from RKB (Glacier#l) (87.00 Ft above mean sea level: Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 163.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. I I I; . ....!; Prepared For: MARAT ONOILCOMPA Y Wen KBU 23-7 Kenai Peninsula, Alaska Prepared by: Ton.y Tykalsky Reviewed by: Dewees Presented to: David CastiU Revised December 10, 2003 e e elÆ Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 A TTN: David Castillo David: Enclosed is the revised drilling fluid program for the KBU 23-7 Well to be drilled next year. The following is a brief synopsis of the program. Overview: KBU 23-7 is a development well targeting the Middle Beluga and Tyonek formations at the Kenai Gas Field. F10-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 3-112" liner cemented in place. Surface Interval: The surface interval will be drilled with the standard GellGe1ex spud mud. Based on offset well data, no problems are anticipated during this interval. 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 F10-Pro KC1 fluid. SafeCarb bridging material will be maintained according to the mud program to minimize losses to the formation. Fluid loss should be maintained @ 7 -9 cc's API. Whole mud losses to the depleted Sterling and Beluga sands are the biggest issue. Production Interval: This interval will be drilled with the modified Flo- Pro fluid. After drilling out the intermediate cement and 20 - 25 feet of new hole, the well will be displaced to a modified F10-Pro KC1 fluid. Fluid loss should be maintained @ < 6 cc' s API for this interval. Gas encountered may require the mud weight to be increased to +/ - 11.0 ppg. Completion: This program assumes the well will be completed with 6% KCl brine. Tony Tyka1sky Proj ect Engineer M-I Drilling Fluids Reference Wells: KBU 43-7X, KBU 42-7, KBU 24-6 NOTE: This proeram is provided as a euide only. Well conditions will always dictate fluid properties required. r:zj fllÆ ~~ m ~ ~ fllFE -- - Marathon Oil Company Well Name: KBD 23-7 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 KBU 23-7 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. r:zj _.FE ~~ e e .FE Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth BenChmark Benchmark 2 - , '3 Benchmark 4 ..., ....'¥... InterVal ,..., (ft) > Fluid cost per foot Volume Usage Solids Removal 0- 1400' > $7.75 ft > 1792 bbls 1400 - 6588' > $37.46 ft > 3633 bbls 6588 - 9133' > 28.39 ft > 1414 bbls Total Project Avg. Max. Targets for < $30.38 < 6839 bbls < $0.23 lb No Spills from Centrifuge Drilling Van Operation Interval r:zi ..FE ~~ Marathon Oil Company Well Name: KBD 23-7 Location: Kenai, Alaska. GellGelex Spud Mud Screens 150/180 mesh Desilter Centrifuge Van 5 5296' Flo-Pro 9.0 - 9.6 w/SafeCarb reens 180 - 210 mesh Desilter Centrifuge Van 3-112" 8-112" 13' 7725' w/SafeCarb Screens 230 - 210 mesh Desilter Centrifuge Van 3 112" 8-112" Completion 9113 7725' 6% 8.55 2 ~ 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). ~ Condition the mud prior to running casing for an intervals. ~ Cost does not include any considerations for whole mud losses. e e Marathon Oil Company Well Name: KBD 23-7 Location: Kenai, Alaska. Product Usage Summary M-I Bar 0 182 141 0 323 1.4 M-I Gel 359 0 0 0 359 1.7 Gelex 45 0 0 0 45 0.2 Soda Ash 13 18 7 0 38 .2 Caustic Soda 18 36 14 0 68 0.6 Conqor 404 0 8 5 0 13 5.0 SafeScav NA 2 8 3 0 13 1.7 Bicarb 18 18 14 0 50 0.3 Conqor 303 0 0 0 6 6 1.0 FloVis 0 327 113 4 444 29.8 Desco CF 9 0 0 0 9 .14 DualFlo 0 0 141 0 141 3.95 Polypac UL 18 145 0 0 163 8.7 Greencide 25G 0 0 2 0 2 1.2 Bioban BP Plus 0 0 113 0 113 0.85 KCI 0 1526 594 210 2330 10.0 Safecarb 0 1450 424 0 1874 11.2 SafeKleen 0 1 1 1 3 0.45 Lubetex 0 42 8 0 50 12.5 Defoam X 0 40 16 0 56 1.7 Klagard 0 32 0 0 32 7.6 Engineer Service 5 10 7 2 24 r:zj ..FE œr~ e e elR Marathon Oil Company Well Name: KED 23-7 Location: Kenai, Alaska. Offset Well Information Well Hole Size Depth PPG PV YP FL Comments KBU 43-7X 16" 1500 9.15 14 30 14 Spud in, drlg to casing point 12.25 2900 9.2 5 24 16 Drlg out, disp to FloPro (no fluid loss) 4225 9.05 9 21 16.4 Drlg ahead, encounter some coal 4810 9.32 9 30 15.6 Short trip - backream - some swelling 5112 9.4 11 30 17.6 Swelling hole - lower FL with Pac 5811 9.5 13 29 8.4 POH-OK 6477 9.6 17 42 6.0 POH - ready to run casing 8.5 6991 9.2 12 22 4.4 New mud - drlg ahead 7795 9.3 14 26 3.6 Trip OK - drlg ahead 8570 9.85 12 44 4.4 Gas - increase mud weight 8610 10.6 15 28 4.6 Gas - increase mud weight KBU 42-7 17.5" 1006 8.9 12 30 11.2 Spud in, drlg to casing point 1760 9 12 19 116 Drlg out, LOT 15.6 ppg 12.25" 3455 9.3 10 17 8.9 Drlg ahead 4371 9.35 9 25 11 Trip OK 5205 9.4 14 11 5.5 Drlg ahead, some losses, 100% losses @ 4899' pump SafeCarb LCM (M & C) 5590 9.3 14 18 7.6 Drlg to csg point, spot LCM pill, lost 50 bbls during cementing 8.5" 6131 9.7 13 24 10.8 Drlg out, LOT 13.3 6733 10 15 19 8 Hole swelling, inc mud weight to 10.0 ppg 7000 9.9 15 19 7.8 Drlg ahead 7293 10.15 15 21 7.5 Drlg ahead, inc mud weight to 10.3 popg 7570 10.6 22 22 6.6 Drlg to TO increase mud weigh (gas) KBU 24-6 17.5" 1008 8.85 28 67 7.5 Spud in, drlg to casing point 1525 8.65 12 26 11.4 Sweep hole prior to running csg 12.25" 1818 8.75 7 27 6.2 Drlg out, LOT 18.4 ppg 3611 8.95 8 20 6.9 Drlg ahead 4011 9 8 16 7.8 Drlg ahead 4532 8.9 8 22 8.2 Drlg ahead 4982 9.7 9 22 10 Drlg ahead 5213 9.8 11 27 8 Drlg ahead 5505 9.6 7 14 7.8 Run csg, lost returns spot LCM pill (1289 bbllosses) 8.5" 6395 9.55 8 25 7.7 Drlg out, LOT 14.5 ppg 7420 9.6 9 27 7.5 Drlg ahead, inc mud ppg 7500 10.3 11 25 6.2 Spot 16.0 ppg pill on bottom, run liner r:zj .IÆ ~~ e e ~FE Marathon Oil Company Well Name: KBU 23-7 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 formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. => FLUID LOSS CONTROL - In the intermediate 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 LSRV. => 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 determining 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. r:!j .IÆ ~ e e Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Interval Summary -16" hole > o .. 1400' ... 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 Interval Drilling Fluid Properties Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec.!qt) (lb.!100ft2) (mI/30min) (%) 0- 1400' 8.6- 9.2 60 - 100 25 - 35 NC - 12 +/- 9.5 <7% )0> Treat drill water with Soda Ash to reduce hardness. )0> Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. )0> Lower funnel viscosity to +/- 75 after gravel zone has been drilled. )0> Add Gelex as needed to maintain sufficient viscosity for hole cleaning. )0> Increase funnel viscosity if fill on connections begins to occur. )0> Reduce fluid loss with additions ofPolypac Supreme UL prior to running surface casing. )0> Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. )0> Condition mud prior to cementing casing to reduce yield point and gel strengths. )0> Estimated volume usage for interval- 1792 barrels. )0> Estimated haul off volume - 2784 barrels. ~ ..FE ~~ e e fiFE Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Interval Summary - 12-1/4" hole Drilling Fluid System Flo-Pro Fluid 1400 -6588' Key Products Flo- Vis / PolyPac UL / KCI / SafeCarb F & M, Asphasol Supreme / ubetex / 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 » Intervàl Dril~ing Flul<.l:.,Properties Depth Mud vi Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) ( cp.) (cps) (ml/30min) (%) 1400 - 3500' 9.0- 9.4 8- 12 40,000 8 - 10 +/- 9.5 +/- 5% 3500 - 6588' 9.2-9.6 10- 14 40,000 7 - 9 +/- 9.5 +/- 8% ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo- Pro fluid using the enclosed fonnula. ~ 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, treat with a 2 PPB addition of Asphasol Supreme ~ Estimated volume usage for interval- 3633 barrels. ~ Estimated haul off volume - 6048 barrels. ~ Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~.IÆ ~~ e e elÆ Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Intermediate Interval Fluid Formula 12-1/4" Interval from 1400 - 6588' Input Description KBU 23-7 Intermediate Interval Mud Weight 9.1 - 9.2 Prehvdrated Gel No Weight MaterialCødø MI Bar Preh . GèlCliê. Weight MateriàlSG 4.2 KCI Wt% 6 Output - 1 bbl I Order' ·of Products ¡¡¡ ÖP,,",,"" ,;¡)Ji VVIU', ",¡¡" Addition ' Fle:ld.lb Lab,gOl jmreld. bbl (ab,ml Usadi¡ 1 Water 298.70 298.70 0.853 298.70 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 2.00 2.00 0.004 1.33 Viscosity 4 Polvpac Supreme UL 2.00 2.00 0.004 1.25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 pH Control 6 Potassium Chloride 19.07 19.07 0.023 7.98 Inhibition 7 KlaGard 4.00 4.00 0.012 4.16 Inhibition 8 SafeCarb F 10.00 10.00 0.100 3.58 Bridging Agent 9 SafeCarb M 10.00 10.00 0.100 3.58 Bridging Agent If coal sloughing becomes a problem, add the following: 10 Asphasol Supreme 4.00 4.00 0.012 4.08 Well bore Stabilitv If bit balling becomes a problem add the following: 11 D-D CWT 1.00 1.00 0.003 1.00 Reduce BHA Balling If toraue becomes a problem, or sliding is difficult, add UP to 5% of the following: 12 Lubetex 14.00 14.00 0.041 14.43 Lubricity Total 399 399 1.000 350 Calculated Mud Weight 9.1 Estimãtød Vol!Jmø0jl~ge 3633 Barrels Total Chloride 29600 ~ ..FE œr~ Marathon Oil Company Wen Name: KED 23-7 Location: Kenai, Alaska. 0.9 " 0 - " .., ." 0.6 œ is ~ ¡;; ., 0.6 " :e '" "- " ,. '" 0.4 '" :; E " (j 0.3 0.2 0.1 ~X10-2 M@raHlon Oil Companv WolI Nam.: Lo<::atiofl: ~1999 M.Il.L.C" All Rights Reserved Permeabillity. zono mDarcy Particle Size (microns) DlO Target/Blend: 2.21 2.7 microns D5f) Target/Blend: microns D90 Target/Blend: 178.91 27£.1 micro-os Brand Name ~ ~ ){!!!JI I B...Safe Carb (F) 17.5 0.3 1.47 C=Safe Carb (M) 17.5 14.1 70.50 D""Safe Carb (q 17.5 5.6 28.Q3 B 1.5% Total Unit Cost: 17.50 20 ppb 0.89 % 9.81 % Calcium Carbonate added: Avg Error 10.90 % CPS Range: Max Error 10..00 % CPS Range: )õ> Zone of interest - Sterling Sands )0> Pore Pressure 1.5 ppg - Maximum Porosity - 2000 mD )0> Measured Depth - 4239' )0> Build additional volume as needed using the blend listed above. Marathon Oil Company Well Name: KBU 23~7 Location: Kenai, Alaska. Operator: Mara¡l1on Oil Companv W*I! Nam$: Permeabillity: 1000 mDarcy Field of) 1999 M-I L.L.C - All R.ighte Reserved c o '" " ~ <II i5 ~ Ö; " -¡¡ 'E .. 0- .. ,. '" .. :; E " (j 010 Target/Blend: 1.61 2.3 microns 050 T argetlBlend: 39.1/ 31.6 microns 090 TargetfBlend: 126.61 130.5 microns ~ UnitCostf$\ CaC03'pub\ ~ B".Safe Carb (F) 11.5 0.3 1.21 C=Safe Carb (M) 17.5 18.1 9O.¡¡8 D=S-afe Q,rb (C) 11.5 1.1 8.35 B 1.3% C 90.4'1\ Total Unit Cost : Calcium Carbonate added: 17.50 $ 28 ppb 1.11 '1\ 2.13 % Particle Size (microns) Avg Error 10-90. % CPS Range: Max Error 10-90 % CPS Range: >- Zone of interest - Upper Beluga Sands )P> Pore Pressure 1.5 ppg - Maximum Porosity - 1000 mD )P> Measured Depth - 5702' )P> Build additional volume as needed usin2 the blend listed above. e e ~IFE Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole 6588...9113' Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / DualFlo / KC1/ 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 Drillin~F!Jrid·..~opertiesi ·i./ .. '... Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) (cp.) (cps) (ml/30min) (%) 6588 - 91 13' 9.0+ - 10.0+ 10 - 14 40,000 < 5 +/- 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- 1414 barrels. ~ Estimated haul off volume - 2298 barrels. ~ Condition mud prior to running 3-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~.IÆ rœ'~ e e fiFE Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Production Interval Fluid Formula 8-/12" Interval from 6588 - 9113' I Description Mud Weicht Weicht Material Code Weicht Material SG Input KBU 23-7 Intermediate Interval 9.1 - 9.2 . Gel MI Bar 1- . . Gel Cone. 4.2 I KCI vvì01& 6 Order of Addition 1 2 2 3 4A 4B 5 6 7 8 9 ~"~"'" No """" Output - 1 bbl Concentration Field,lb Lab," crnFieldi5"~~Î Water 325.19 325.19 0.929 Soda Ash 0.25 0.25 0.000 FloVis Plus 2.00 2.00 0.004 DualFlo 3.00 3.00 0.006 SafeCarb Fine 15.00 15.00 0.150 SafeCarb Medium 5.00 5.00 0.050 Potassium Chloride 20.76 20.76 0.025 Greencide 25G 0.25 0.25 0.001 CONQOR 404 2.00 2.00 0.004 Caustic Soda 0.50 0.50 0.001 SafeScav NA 0.25 0.25 0.001 If Bit ballina becomes a problem. add the followina i i D-D 4.00 4.00 0.011 4.00 If sliding or high toraue becomes a problem add 1 - 3% of the following Lubetex 7.00 7.00 0.021 7.00 Ifsloughi~"~~c;ºrne a problem add 2 - 4 ppb of the following Asphasol Supreme 2.00 2.00 0.004 1.33 Mix fllJi<U"!1 the ºrdE:!rli~tE:!dabove.V\I~it!2~J ~"" ?-9lr~lJlª~2!1s~l:>eforE:! add il1g~ """""~""""" SafeScav NA to the ~stem. Alternate" adclitions of Greencide 25G and SafeScav NA ~s need"E:!~. _~==~~~~~"~~" " """ ;~- " ""r - """" 5"~r===- Maintain fluid loss at or below 6" API with DualFlo additions. ,. '",...-. . ,,'-~ "-,~~~~~._" ".~_.,.., ,~~.",....,.,.~,., -..... Reduce concentration of FloVis as needed to maintain rheolocv. Products Lab, mI 325.19 0.10 1.33 2.00 5.37 1.80 8.68 0.30 1.43 0.23 0.25 I I Total Calculated Mud Weiaht Total Chloride 380.1 380.1 9.050 29600 1.000 350 ~ ..FE ~~ """ " I Usaae Reduce Hardness Viscosity Fluid Loss Control Bridging Agent Bridging Agent Inhibition Bacteriacide Corrosion Control pH Control I Oxvcen Scavencer Bit Balling Lubricity Wellbore Stability i 0.00 , e e elFE Marathon Oil Company Well Name: KBU 23-7 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 of the Drilling Fonnan. 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 infonnation. 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. r:zj .IÆ ~~ Marathon Oil Company Well Name: KBU 23-7 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 Materi Bridging and weighting agent Weighting agent Loss Circulation Material Loss circulation Material Loss circulation Material Dispersant Dispersant Dispersant Surfactant Densifier Densifier Shale Inhibitor IFE - Product CAUSTIC SODA CAUSTIC POTASH BORAX SAPP ODA ASH DIUM BICARBONATE CITRIC ACID BIOBAN BP-PLUS GREEN CIDE 25G - DEFOAM X - G-SEAL KLA-GARD LUBE TEX D-D CWT Concor404 SAFEKLEEN sphasolD Soltex. SafeScav NA Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. Function Ikalinity control H Modifier Inorganic Borate Sodium Pyrophosphate Ikalinitycontrol Ikalinity control pH Adjuster Biocide iocide Defoamer Sized graphite LCM Shale Control agent Lubricant Detergent Corrosion Inhibitor Drilling fluid additive Shale Inhibitor Shale Inhibitor Oxygen Scavenger e e - _IFE Marathon Oil Company Well Name: KBU 23-7 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 r:m elÆ ~~ Marathon Oil Company Well Name: KBU 23-7 Location: Kenai, Alaska. . MI Project Engineer and Tech Service Engineer will coordinate between the Marathon office, rig, warehouse, and the M - I field engineers. . Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. Project Team Title Home Cellular Craig Bieber District Manager 907 345-1239 907 229-1196 Deen Bryan Tech Service 907373-2713 907 223-1634 Tony Tykalsky Project Engineer 907 376-4613 907 227-2412 Gus Wik Warehouse Manager 907776-8722 907 776-8680 Bob WiHiams Senior Engineer 907 248-5857 907 590-3636 Locke Rooney Senior Engineer 907349-8147 907 590-3636 Check No Check Date Bank Bank No Marathon Oil Company P. O. Box 3128 Houston, TX 77253 ~ð~~UI~¥~ir~~Y~~LE DEPARTMENT Accts Payable - Customer Serv Phone: 713-296-4336 Þ¥#MM Hndlg AL 1106443 12/15/2003 NCBAS 7780 @@Þ.~iiM@~f )i®~¡WÞ~W P¥Gm~WM~ 0100. 00 12/12/2003 1900034822 OTAL: ...%¥@I.~Am@RI) . 100.0 100.0 Alaska Oil & G s Cons. C A horage (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) 11·000 I. 1.0 b ~ ~ ~". 1:0 ~ I. 20 ~B '151: 0 ¡'B ~ ~B ~". e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLffiS (OPTIONS) M1JL TI Tbe permit is for a new wellbore segment of LATERAL existing well ~ Permit No, API No. . (If API num ber Production sbould continue to be reported as last two (2) digits a function of tbe original API number stated are between 60-69) above. P~OT BOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) . and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe 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 exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. Rev: 07/]0/02 C\jody\templates Field & Pool KENAI, UPPER TYONEK BELUGA GAS - 44857 Well Name: KENAI BELUGA UNIT 23-7 Program DEV Well bore seg D PTD#: 2032170 Company MARATHON OIL CO Initial ClasslType DEV 11-GAS GeoArea Unit On/Off Shore On Annular Disposal D Administration 1 PermiUee attachep_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leasenumberappropripte_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nique weltna!lle_and ou.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Ves _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ 4 WeUJocptedinadefil1eppooi. _ _ _ _. _ _ _ _ _ _ _. . _ _ _ _ _ _ _ _ _ Yes_ _ . _This is pnewlydefined_po_otio the KeoaiField_ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _. 5 WeJlJocpted proper _distance_ from driJIing ul1itb_oul1d;;¡l)'_ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ 6 WeUJocptedprpper_distancefromotberwelJs. ________Yes______._. _______ _______.. _______ 7S_utfjciel1l.acreag.e_ayailpble [ndJilliog unjl. _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ 8 Jf.devi¡¡ted, js_ weJlbore platil1cJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 9 _Operator ol1l~ affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ 10 _Operator bas_apprppriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ . . . _ 11 Permit c.ao be issued wjtbout co_nserva.liOI1 order. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . Appr Date 12 Permit ~ao be issu.ed wjtbout ¡¡d.mil1istrativ:e_apprpval _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ _Ves _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . RPC 12/16/2003 13 Can permit be approved before 15-day wait Ves 14 WellJocated withil1 area and_stratp .authorized by.lojectioo Order # (puUO# in_cpmmeots).{For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 15 _AJI wel!s_wit!1in Jl4_llJile_area_of reyiew jdeotified (Fpr s.ervjce.w.ell OI1I~>- _ _ _ _ _ _ _ _ _ _ _ _ _ . _NA _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . . . _ _ . . . . . . . . . . _ . _ _ . . . . . . _ _ _ _ . . . . . _ _ . _ . . . 16 PJe-produced injector; pur<ltion.of pre-propuctiol1less_ than:3 mOl1tbs. (Forservlce well Qn!y) . . .NA . _ _ _ _ . _ _ . . . . . . . _ _ _ . . . . . . . . .. . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ . . . . 17 A.CMPF'il1djngofCQn~tstency.h_as bee.nJs.sued_forJbis proiect _ . _ _ . . . . _ _ _ _ _ _ _NA . . . . . . . _ . . . . . . _ . _ . . . . . . . . . _ _ _ _ _ _ . . 18 19 20 21 22 23 24 25 26 27 Date 28 12/16/2003 29 30 31 32 33 34 Engineering Appr WGA Appr RPC 35 36 Date 37 12/16/2003 38 39 Geology Geologic Commissioner: e .C.onductor stringpJQvided _ _ . _ _ . . . . . . . . _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ Yes. . . .. .. _ _ _ _ _ _ _ _ . . _ . . . . . . .. _ _ _ _ _ _ _ _ _ _ . _ . . . . . . . . . Surfaœcasil1gpJote~ts. all.known USQWs _ _ _ _ _ _ _ _ . _ _ . . . . . _ _ _ _ . . Yes. . _ _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ _ _ _ _ . _ _ . . . . . . . . CMTv_oladeQu.ateJocircutateon_cOl1ductor_&su.rf.C$g... . Yes. _ _AdeJ:uateexces.s, _ _ _ _ _...... _ _ _ _ _ _ _ _ _ _ _ _ _.... CMT vol adeQu.ateJo tie-lnJong .string to surf cs.g_ _ _ . . . . . . . . No . _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . . _ . . . . . . . _ _ _ . . . .. ... _ _ _ _ _ _ _ . . . .CMTwill coyer aU klJow.n_pro_ductiYe borizons. . _ _ . . . . . _ Yes. . _ . . . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ . .. . _ _ _ _ _ _ . . C_asiog designs ¡¡dequa_te fpr C,.T, B.&.Rerruafrpst _ _ _ _ _ . . . . . . _ Yes. _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ . . . .Adequ<lte.tankageoJ re_serve pit _ _ _ . . . . . . . . _ _ . . . . . . _ _ _ _ _ _ _ Yes _ . . . . . . GI<lcierRig #1.. _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . _ . . . . . _ _ _ _ . . . . _ _ _ _ _ _ _ _ Jf.aJe-priIL has.a. 1.0,403 for <lbandonment beeo aPPJoved . _ _ _ _ . . . . . . . . . . NA _ _ . . . ~ew welt _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . . _Adequ<lte.w.ellbore s.ep¡¡ratjon.proPÇ)sep. . _ _ _ . . . . . . . . . . . . . _ . . . _ . _ . . . . _ . . . Yes. _ _ _ _ _ _ . _ _ _ . . . . . . . _ . _ _ _ _ _ . _ . . . . _ . _ . _ . . . _ _ . . . . . _ . _ . . . . . . . . . . . . _ _ . . . . . . . . . . . . Jf.djvecter Jeq.uiJed, does il.meet reguJatiol1s_ _ _ _ _ . . . . .. . _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ Yes _ _ . . . . . . . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _DJilIiogf]ujd.RrogJams~hematic&eCl-uipJistadequpte.... _ . _ _ _ _ _ _ _........ _ _ Yes_ _ _MaxMW.tOcO_ppg. _ _ _ _ _ _...... . _ _ _ _ _ _......... . _ _ _ _ _ _.. _.... BOPEs, do they meet reg uJa.tio IJ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . Yes. . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ . . . . . . _ _ _ _ . . . . . _ _ . . . . .BOPE.pressratiogappropriate;testto_(pu.tpsigln.commelJts>- _ _ _ _ _ _...... _ _ _ _ _ _ _Yes .Testt03500psi..MS~28Mpsi.. _ _ _ _ _ _ _ _ _ _... _ _....... _ _ _ _ _ _ _ _ _ _ _ _ _..... _ _ _ _ _ _. .C.hokemanifold compJies w/APt R~-5:3 (May 84) _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ Yes. . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ . . . _ Work will occur withoutoperatjon .shutdown_ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ . . Yes _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . . Js presence of H2S gas. prObable _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ . . . . No _ _ _ _ _ _ _ _ _ . _ . . . _ . _ _ . . _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ . . . . MeçbanicaLcolJdJlionpfwellswithiI1AORyerified(for_s_ervjcewel!onJy).. _ _ _ _ _ _ _ _ _ _. _ NA... _ _ _ _ _ _ _ _ _ _ _ _... _... _ _ _ _....... _ _ _ _ _..... - - - - - - - - - - - - - - - - - - - e Permit can be issu.ed wlo. hydrogen. sulfide meaSures _ _ _ . _ _ . . . . _ _ _ _ _ . _ _ . _ . . Y.es _ _ _ . _ . . . . . . . _ _ _ _ . . . . . _ _ _ . . . . . _ _ _ _ _ _ _ _ _D_ata_PJeselJted on. potential oveJpressure .ZOl1es. . . . . _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ NA _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . . _ . . . Sei~m[can¡¡lysjs of sbaJlow gas.z.ooes. _ . _ . . . _ NA . _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ . . . _ _ _ _ _ _ _ _ _ . . . .Seabed .colJdjtiolJ survey.(if off-sh_ore) . . _ _ _ _ _ _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ _ . _ .NA . . . _ _ _ _ . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . . . . . . . . . _ _ . . . . . .. . _ _ _ _ _ _ . . . _ _ Conta.ct l1amelp!1oneJorw.eekly progress_reports [exploratol)'only] _ _ . . . . . . . _NA . . . . . . . . _ _ _ _ _ _ _ . _ . . . . . . . _ _ _ _ _ _ _ . . . . . . . . . . . . _ . _ _ _ _ _ . . . . Date: Engineering Commissioner: ~ - -J Public Commissioner Date Date