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185-255
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: Oil ❑ Gas E] SPLUG ❑ Other ❑ Abandoned ❑� , Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development O Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or an .. 8/26/2019 14. Permit to Drill Number / Sundry: , 185-255 / 318-314 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. 13 -ate -Spudded: 11/6/1985 15. API Number: 50-133-10132-02-00 4a. Location of Well (Governmental Section): Surface: 657' FNL, 1985' FWL, Sec. 16, T7N, R9W, SM • Top of Productive Interval: N/A Total Depth: 441' FNL, 1906' FWL, Sec. 16, T7N, R9W, SM 8. Date TD Reached: 12/4/1985 16. Well Name and Number: Soldotna Creek Unit (SCU) 216-16 9. Ref Elevations: KB: 168' • GL: 148' • BF: 17. Field / Pool(s): Swanson River Hemlock Oil - Tyonek Gas ' 10. Plug Back Depth MD/TVD: 0' MD / 0' TVD. 18. Property Designation: FEDA028993 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 344277.7 • y- 2450058.2 Zane- 4 TPI: x- N/A y- N/A Zone- 4 Total Depth: x- 344191.0 y- 2450278.7 Zone- 4 11. Total Depth MD/TVD: . 11,005' MD / 11,000' TVD . 19. DNR Approval Number: N/A 12. SSSV Depth MDfTVD: N/A I 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes LJ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 121. N/A ift MSL) I Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" Surface 36' Surface 36' 11-3/4" 47# J-55 Surface 2,035' Surface 2,035' 16" 1600 sx 7" 23,26,29# N80 P110 Surface 8,704' Surface 8,703' 9-5/8" 1st 600 sx, 2nd 1200 sx 5" 18# N-80 8,704' 11,004' 8,703' 10,999' 6" 275 sx 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): A1o`"�On 24T VERIFIED _-_ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yeso No e • Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: N/A Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 Revised 6/20171/ 1 '�'/ CONTINUED ON PAGE ;ABDMS L'r OCT 0 9 2019 Submit (IGINAonly, ! j2 -a 3 -1,7 28. CORE DATA Conventional Core(s): Yes ❑ No 0 . Sidewall Cores: Yes ❑ No ❑✓ - If Yes, list formations and intervals cored (MDlf VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary, Schematic, MIT -IA, Photo document casing cut-off/cement top/welded plate. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York 907-777-8345 Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkramero&hilcom.com Authorized �,yl,:- :tsx Contact Phone: 907-777-8420 r1/1 Signature: Date: / S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Forth 10-407 Revised 5/2017 Submit ORIGINAL Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 21B-16 50-133-10132-02 1 185-255 9/11/18 8/26/19 Daily Operations: 09/11/2018 -Tuesday Hold safety meeting. Obtain PTW. Lay out liner. Spot equipment. RU CTU equipment. Spot and berm 2x rain for rent tanks. 24 hr BOPE test witness notification sent 9/10/18 @ 15:15. Witness waived via phone call to North Slope inspectors office and Matt Herrera 9/11/18 @ 11:00 hrs. Start BOPE test. Test all rams and valves to 250/3,000 psi. Accumulator draw down test. BOPE test good. Location secure. SDFN. 09/12/2018 - Wednesday PTW. JSA. Vac trucks hauling 60 bbls at a time to load supply tank. Mixing Friction reducer (j609W) shearing through SLB pumps and blenders. Pollard arrive on location to pull pack off plug. Spot in Pollard. Perform SIMOPS. Pollard hot shot tools arrived. RIH with Pollard Slick line and remove pack -off plug. Location secure. SDFN. 09/13/2018 -Thursday PTW. Hold safety meeting. Make up BHA. Presure test lubricator 250/3,500 psi. Good test. Bleed down and RIH pumping min rate. Tagged down at 5,028'. Pick up and perform multiple gel sweeps and wiper trips back to tubing tail. Continue to work through sand bridges. Tagged PBTD at 6,577'. Circulated 10 bbl gel sweept and chased it out of hole. Parked at 300'. Line up down coil and coil backside to perfom injection test better. Come oneline and pressure slowly walking up .5 bbls/min and climbing. 1,500 psi shut down mud pumps. Pressure slowly dropping, formation seems tight or not much permeability properties. At surface. Well closed in. Rig down CTU. 09/28/2018 - Friday Sign in and mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3000 psi. RIH with 2.19" spiral plug at 50 fpm and tie into SLB Plug Set Log dated 19 -Sep -02. Tag fill at 6524'. Ran correlation log. Got ok to set it and send log later. Spotted and set plug at 6500'. Lost 100 Ib line tension when plug set. Pick up 30' and went back down and tagged ' plug. Good set. POOH and everything looked good. BLM witness plug set (Allie/Amanda). RIH w/2 -1/2"x40' dump bailer filled with 17 ppg NEO cement and dumped cement on top of plug at 6500'. Made 2 more cement dump bailer runs. TOC should be +/- 6480'. Will come back in morning, tag cement and make 3 to 4 more bailer runs depending on TOC. TOC need to be 6465' or less. Rig down lubricator and secure the well. Will be back at 7 am in the morning. Cement samples are at the office. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 21B-16 50-133-10132-02 1 185-255 9/11/18 1 8/26/19 Daily Operations: 09/29/2018 -Saturday Sign in and mobe to location. PTW and JSA. Work on Brice crane. Could not get it to swivel. Called Brice Company who it was rented from. AK E -Line crane is getting worked on. Troubleshoot and got it to work. Rig up lubricator, PT to 250 psi low and 3000 psi. TP - 0 psi. RIH w/2 -1/2"x40' dump bailer filled with 17 ppg NEO cement, tag TOC at 6490' and attempted to dumped cement on top cement dumped yesterday. POOH. Cement didn't dump and was partially set up in bailer. Clean out bailer. RIH w/2 -1/2"x40' dump bailer filled with 17 ppg NEO cement, tag at 6500'. That is where the plug was set. When plug is set and left in hole it is 8' long. We dumped 17' of cement on top of plug. We tagged at 6524' (Top of Perf) with plug before we set plug yesterday. If you add plug and cement it adds up to 25' (top of perf). Called town and discussed. AK E -line and I are thinking that cement pushed plug to top of perfs,which would leave TOC at +/- 6500'. Also was thinking that the tag at 6490' was a cement stringer. Decision was made to call BLM and get ok to go ahead and dump bail 35' of cement. I called Amanda Eagle with BLM and got the ok to do it without setting another plug. She had witness the plug setting and tagging of the plug yesterday. Went ahead and dump bailed 8.25 gals (5.28') at 6500'. POOH Good dump. Made 4 more 2-1/2"x40 dump bailer runs with 17 ppg Neo cement. TOC est at 6474'(5 runs total = approx. 41 gals). Rig down lubricator and secure well. NOTE: We will be back in the morning between 9 and 9:30' am to tag TOC and finish off cement. Should be 2 to 3 bailer runs depending on tag depth. Ls' P�6 09/30/2018-Sunday Sign in and mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3000 psi. TP - 0 psi. RIH w/CCL-GR and tie into plug log. Tag TOC at 6466'. Run correlation log and send to town. POOH. Make up bailer and mix cement. RIH w/2 -1/2"x40' cement dump bailer filled with NEO 17 ppg and tag TOC at 6466'. Dump cement on top (est 5.25' of cement)). POOH. Good dump. RIH w same bailer and dump on top of cement at 6461' (est 5.25' of cement. TOC est at 6455.6'. CIP at 1330 hrs. Both dumps good. Rig down lubricator and secure well. Be back in the morning to tag, Jet cut and pressure test Tubing/IA. I notified both AOGCC and BLM that we would be ready to tag at 1300 hrs. Then jet cut and then pressure test tubing/IA to 2000 Psi and chart it. 10/01/2018 - Monday Sign in and mobe to location. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3000 psi. TP - 0 psi, RIH w/2-1/2" Jet cutter, tied into yesterdays log and tagged TOC at 6454'. Ran correlation log and spotted jet cutter at 6130'. CCL stop depth was 6126.3' (3.7' from CCL to Jet cutter). Fired cutter. Felt jet cutter go off on the wire line and also heard it at the well head. POOH. TP - 0 psi and IA - 0 psi. Rig down Equipment and secure well. Hooked up crystal gauge to tubing and tri- plex to IA. Pump up to 1000 psi and let settle for 3 min. Pumped up to 2200 psi a couple of times and pressure would bleed down 100 psi and still losing but slower. Pumped up to 2221 psi and left for 30 min. Pressure bleed to 2071 psi (150 psi). There is a small leak on the stem of wing valve. Going to leave gauges on overnight and see what it is. Will get the valve man to look it in the morning and grease it. •r J Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 21B-16 50-133-10132-02 185-255 9/11/18 8/26/19 Daily Operations: 10/02/2018 -Tuesday Meet with Peak and valve man down at location. He tightened packing and grease tree valves. Pressured up tubing/IA to 2196 psi. Well bled down to 2149 psi in 15 min (47 psi) and to 2110 psi (39 psi last 15 min) in 30 min. Lost 86 psi total. Middle master stem would leak every once in a while. Turned middle master back 1/8 turn seemed to help. Bleed tubing down to 0 psi to blow down tank to see if any air was in tubing. Got some air back. Had crystal gauge hooked up to tubing and pumped down IA. Hook crystal gauge up to IA and closed the two masters and swab valve. Put regular gauge on night cap. Started a new test on crystal gauge and while pressuring up bottom master stem leaked. Got it to stop and went ahead and pressured up to 2081 psi. After 15 min it was 2039 psi (42 psi lost) and after 30 min it was 2010 psi (29 psi lost in 15 min) for a total of 71 psi lost. Test was from 1141 hrs to 1211 hrs. Break for lunch and called town. Discussed with town and it was a good test. Rig down crystal gauges and triplex. Secure well. 10/12/2018 - Friday Reviewed JSA, Discussed daily work plan, reviewed recent incidents and expectations, reviewed daily hazards and mitigations. Check pressure on well head SITP = 30 psi, SICP = 30 psi, Start equipment and prep location to begin spotting equipment and rig up. Spread herculiner, Bled residual pressure from tubing, with pressure at 0.0 psi and no flow noticed, started configuring tree so rig could spot in correctly, spotted in rig and stood up derrick to half mast, continued spotting equipment and preparing for rig up. Hold rig up safety discussion. Continued spotting and rigging in equipment, stood derrick up to full mast, checked dogs to insure there was full engagement, guyed out to base beam continued with rig up. Inspected new mud pump that was delivered to location and prepared for operations. 10/13/2018 -Saturday Reviewed JSA, discussed daily work plan and activities, reviewed hazards and mitigations. Start equipment and prepare to begin daily operations. Continue rigging up equipment and prep to mix brine once water arrives on location. Water arrived on location, unloaded into Rain for Rent Tank and started mixing 9.6 ppg Brine, while preparing pump to agitate the solution, found that pump valves were seized up. Continued mixing brine, Tore pump fluid end down to evaluate and to repair if possible, found that boost charge pump would not rotate as designed, found that the triplex suction and discharge valves were all seized up and not allow fluid to pass through the fluid end. This was a replacement pump that was sent out to replace the previous mud pump that had a non functional power end oiler. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 2113-16 50-133-10132-02 185-255 9/11/18 1 8/26/19 Daily Operations: 10/14/2018 -Sunday Reviewed JSA, Discussed Daily Work Plan, Reviewed associated hazards and risk mitigations of those hazards. Started equipment and prepared for the days operations. Continued to rebuild the Triplex on the mud pump, replaced all seized valves and seats in the triplex, repaired the liner wash pump system, continued to roll and mix our 9.6 ppg NACL Brine. With pump repairs complete and Mud pump fully operational, Fluid NACL Brine at 9.7 ppg, held a pre job tailgate discussion regarding pressure and high pressure pumping, performed valve alignment with Driller, began pumping at slow rate to until we established circulation to insure system was clear of obstructions. Increase rate to 4 BPM and continued at this rate until we had pumped a full 240 bbls of 9.7 ppg NACL Brine. Shut all valves on the well head, Shut down equipment, performed house keeping, released crew for the night. 10/15/2018 - Monday Reviewed JSA, discussed daily work plan, reviewed hazards and mitigations. Check well for pressure, no pressure noted, Install TWC in tubing hanger, Remove production tree, install plug in hanger, Check hanger threads for landing joint make up, threads were good. Nipple up BOP'S, install kill line and choke line valves, rig up kill line and choke lines. Rig up test sub, test joint, FSV and IBOP, start filling equipment with test media in preparation of performing the BOP test. Performed low and high test on annular, both low and high tests passed 300 Low and 2,625 psi High, setup to perform test on Pipe Rams and FSV, attempted to bring up low pressure but found Pipe rams to be leaking with hydrostatic pressure, worked pipe rams open and closed multiple times, rotated landing joint, attempted to bring pressure up with no increase and noticeable leak at surface, Test failed. Notified Weatherford of the issues and made plans for Weatherford Rep to bring out new ram blocks and tools to make repairs to the pipe rams at 06:00 on Tuesday 10/16/2018. 10/16/2018 -Tuesday Met Weatherford on location, checked well pressures (0.0 psi), Started working to open Pipe Ram Doors to change out the 3-1/2" VBR's for 3-1/2" CBR, Once rams were changed a pressure test was placed on those rams to insure they would function properly and that they would pass the BOP test. Restarted the BOP pressure test from the beginning, BOP Initial Nipple Up Test was completed successfully and Test results recorded on the AOGCC 10-424 Form and have been submitted to the AOGCC. With BOP test complete, prepped equipment to Un land tubing, Backed out lock down pins, cleared floor, and proceeded to pick up to Un land, pick up weight was approx. 43,000 lbs, pulled hanger to floor and removed, installed new collar on tubing stump, made up FSV and secured the well, break for lunch. Crew broke for lunch. Removed FSV, proceeded to POOH with tubing, at first collar it was noticed that the collars were Slim Hole collars (4.10 OD) and could not be POOH with the Square Shoulder elevators that we had on the rig. Made arrangements to get ne elevators delivered to location on 10/17/2018. Continued to use the 2" pup that we had with the new collar (4.27 OD), continued to POOH cutting injection line bands and laying down injection line and tubing, laid down a total of 14 Joints. Process was slow since a connection had to be made up then break out 2 for each joint to be laid down. Estimate finish laying down mid afternoon on 10/17/2018. Prepare to run CBL at that time. Fuel and service equipment, perform general housekeeping and stow tools. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 218-16 50-133-10132-02 185-255 9/11/18 8/26/19 Daily Operations: 10/17/2018- Wednesday Reviewed JSA, Discussed daily work plan, reviewed risks and mitigations. Check well pressures (0.0 psi SICP and SITP). Start equipment, prepare floor for POOH operations. Start POOH with production tubing total out yesterday 14 joints, estimated 180 left to pull. Lunch. Continue POOH with Production tubing, Pulled all the way out of hole with a 2 day total of 193 Full Joints, 1 Cut Off Joint, 3 Pup Joints, 2 Mandrels, Injection Line, All Bands were accounted for, haul in fresh water in preparation of cementing services, notified regulatory agencies, notified Cement service provider, notified E -line service provider. Secure Well, Shut down and service equipment, fuel equipment. 10/18/2018 - Thursday Check well pressures (SICP = 0.0 psi, SITP = 0.0 psi). Reviewed JSA, discussed recent rash of undesirable events and the need for extra caution and attention to ones safety and watching out for each other during daily operations, discussed working with new and multiple teams (E -line, Cement and others). Start rig and support equipment, spot in and rig up E - line, prep tools to run CBL from 6,100' up to surface RIH with CBL tools fill the hole with 9.6ype Brine in order to replace fluid lost due to loss of pipe displacement, thus in order to run CBL to surface, tagged fluid level at +/- 600' pumped 25 bbls, continued to RIH, on depth at 08:00, began logging up at 40 FPM, appeared that TOC was at 4,650'. Open pipe started at 2035 and appeared that cement covering shoe at 2,030' to 2,070', continued logging out of the well at 40 FPM, continue to log out of the well, appears that a possible top job was performed in the 11-3/4" X 7" Annulus from surface down to approx. 55', on surface at 11:00. Send logs to Engineering team for review, rig up and prep to RIH with Legacy Oil Tools Big Boy Bridge Plug CIBP, 5.61 OD. RIH with CIBP, set at 2,150', POOH. Make up perforating guns to RIH and perforate at 2,015' to 2018', Change for pert depths were approved by the BLM Engineer after reviewing CBL and having 40' of cement acr�face casing shoe, perforate and POOH. Attempt to circulate down the 11-3/4" X 7" Annulus, pressured up to 1,000 psi, immediately without establishing an injection rate and with less than 0.25 bbls away, pressured up from 1,000 psi to 1,500 psi and shut down, pressure bled back to 1,000 psi and held solid, realigned valves and attempted to circulate down the 7" and up the 11-3/4" X 7" Annulus, but pressured up to 1,000 psi with approx. 0.5 bbls away. Prep equipment and make up pert guns to perforate at 1,935' to 1,938'. RIH and perforate at 1,935' to 1,938' as outlined in the procedure, perforated and POOH. Align equipment and attempt to pump down the 7" and up the 11- 3/4" X 7" annulus, at 0.25 bpm and 0.5 bbls away pressured up to 1,500 psi, shut down, pressure bled back to 700 psi after 2 minutes and stabilized at 500 psi and held solid. Start RIH with tubing, Ran 10 joints, secured well, shut down for the night. C61 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 2113-16 50-133-10132-02 1 185-255 9/11/18 1 8/26/19 Daily Operations: 10/19/2018 - Friday Reviewed JSA, discussed daily work plan, reviewed recent incidents with new team members (cement crew). Start equipment and prepare to start TIH with tubing, 57 joints left to run. TIH with remaining 57 joints of tubing to reach 2,108', 42' above top of CIBP set at 2,150'. Rig up cementing equipment to the top of tubing string and prep to pump first cement plug. Hold pre job safety meeting with all team members, reviewed tubing depths, pert depths, CIBP depths and cement calculations to insure volumes were all correct. Pressure tested cement lines to 3,000 psi, began pumping and pumped 18 bbls of Class G Neat 15.8 ppg cement, fpllowed by 13 bbls of fresh water displacement, rigged cement equipment off of well and began cleaning up cement equipment, started to POOH with tubing at 30 FPM, pulled 20 Joints of tubing taking ECT from 2,108' up to 1,479'. Pumped an additional 13 bbls of fresh water to insure tubing was clear, good clean returns at pit, shut down and closed in 3-1/2" X 7" Annulus valves, pressured well up to 500 psi to squeeze cement into perfs at 2,015' to 2,018' and 1,935' to 1,938', shut in with 500 psi applied to the well. Perform maintenance on rig and support equipment, prepare for upcoming rig move. Continue to WOC. Rig up wireline and prepare to RIH and tag TOC. RIH with E -Line tools (CCL) and tag top of cement, Tagged up at 1,704 GL, Calculated cement volumes for measured depth were to be from 2,150' up to 1,700', picked up to 1,500' and run back down to perform additional tag, tagged up again at 1,704', good solid cement in place, POOH and rig down release crew. 10/20/2018 -Saturday Review JSA, discuss daily work plan, review hazards and mitigations. Weight up Brine to 9.6 ppg to circulate into well bore before pulling tubing string. Circulate in 78 bbls, surface to surface with 9.6 ppg NACL Brine. POOH with 47 joints of 3-1/2 production tubing. RIH and set CIBP at 160' GL, Rig up HES and prep equipment to pump surface plug, Pick up and RIH with 5 Joints of tubing to spot balanced plug from 160' up to surface. Pump 7 bbls of 15.8 ppg Class G neat cement, pumped 3 bbls of displacement, POOH with tubing and lay down, down hole plugging complete. WOC, start performing general clean up, rig and support equipment and maintenance, start rigging down non essential support equipment, nipple down BOP's, tag top of cement, top of cement at +/- 16' below surface, order cement to perform top out tomorrow. 10/21/2018 -Sunday Rig repair and Rig down prepare equipment to move, tagged TOC at 4' from top of Tubing head, approx well head cut of depth. 08/26/2019 - Monday BLM/AOGCC Inspectors onsite, upon verification of cured cement to surface the wells abandonment plate was welded in accordance with BLM State of Alaska requirements. Swanson River SCHEMATIC Well SCU 21B-16 Actual Completion 9/24/02 Ililmg, Alaska, LIA: CASING AND TUBING DETAIL RKB = 20' SIZE WT GRADE CONN ID TOP BTM. ,. Nrti:SM��M 22" - - - 36' 11-3/4" 47 J-55 S8R Surface 2,035' MY 7" 29 N-80 Butt 6.184 Surface SI' ~N 2 Y' 23 N-80 Butt 6.366 81' 4,821' 7" 26 N-80 L811 6.276 4,821' 6,744' 7" 29 N-80 L8R 6.184 6,744' 7,793' Punch DV L8R 7,793' 7,796' @ 150- 7" 29 N-80 L8R 6.184 7,796' 8,564' 154' 7 29 P-110 L8R 8,564' 8,704' 5" 18 N-80 SCC Butt 4.151 8,704' 11,004' ---------- Tubing 7" Squeezed 3 M Punch @ 3-1/2" 9.2 L-80 Imp. Butt SC 2.881 6,140' 6,226' W/SOOsx @ 1,935'- 212' (,935' PT to 3000 JEWELRY DETAIL psi Punch @ NO. Depth ID OD Item 2,015' - 1 0 Tubing Hanger, 3-I/2" 4 2,018 2 160' CIBP cement to surface 10/20/18 5 3 2,150' CIBP w/±300' of cement 10/19/18 6,140' 4 6,145' 2.992 4.750 Anchor, Baker 80-40, KBH Seal Assembly 6 X 5 6,146' 3.250 6.000 Packer, Baker SAB Perm, 84-40 x 32 , 3-1/2" x 7" 7 TOC 6,454' 6 6,193' 2.813 4.500 X -Nipple, 3-1/2", 2.813" ID Tight in 7 6,225' 3.125 4.250 WLEG/Ball Shear Out Sub Casing 8 8 6,500' CIBP w/ 35' of cement -TOC 6,454' 10/1/18 9 6,590' 7" Baker Bridge Plug 6" Bit 9 10 8,569' Crossover, 3.1/2" x 2-3/8" 11 10,270' GLM, 2-3/8" Merla `TMPDX' 12 10,307' 1.875 S -Nipple, 2-3/8" DV Tool @ 13 10,341' 4.00 Gravel Pack Packer, Baker, SC -IL 7 794, 14 10,364' Shear Out Safety Joint, 2-3/8", Baker Cemented w/ 15 10,604' Gravel Pack Screens, 2-3/8" I,200sx 10 16 10,740' Sump Packer, Baker DB Cement Plug tagged in Tubing a[ I l 9,042' Perforation Record Date Zone Tito Bottom Amount Accum Item 12 s SPF 9/25/02 64-5 6524' 6554' 30 4 2-1/2", 6spf, 60 deg PJ 13 H-2 10,606' 10,628' 22' 14 Abandoned H-3 10,644' 10,665' 21' 14 Abandoned H-5 10,684' 10,714' 30' 14 Abandoned 14 15 16 ULN H3 H5 PBTD = 6,590', TD =11,005' MAX HOLE ANGLE = 4deg @9300' DRAWN BY: tcb Updated by DMA 08-29-19 SCU 21B-16 Wellhead Removed/Cemented to Surface ,�, .7028 ° , �` 1•bfl, "' �` o Aft a ..� 08/2: sa'''w - �,,,���i�`+„ '�� e► =x�a rte• � ! 1��� � � ►�� _-02.9° y 1684 rr-• � .ti � S� �v .� 0300 N3O L1533mils TRUE a � w }[ 1 r. f N 030 060 R t.t a SCU 2113-16 Marker Plate Installed 2 PREFS A' 4 X y e[pf, fir` N AOL r r E 3922mRs' TRUEJff , ZE ' 2l q j". I :240 Data Collection Report Chassis Left Scale Right Scale Serial Number 476741 475325 688896 Datatype Lower Upper Units PSI G PSI G Lower Upper PSI G 21 b-16 10-2-18 - 02 -Oct -18,11:31:22, 252 PSI G 2500 0.0 -0.1 2000 1500 -0.2 1000 -0.3 -0.4 500 0 -0.5 -0.6 -500 00� 00' 01^ 'teary N- rye. 000 tk N 00 00• 00 00 00 00 �O`L 00 Elapsed Time hh:mm:ss =PSI G PSI G ata Points Point # Time Left - PSI G Right - PSI G "I Chassis Lower Module Upper BARO Module Module Left Scale Right Scale Serial Number 476741 475325 688896 475325 688896 Model NV 3KPSI 10KPSI 5 00:00:40.0 Message Store -1 6 00:00:50.0 -0.4 -1 Userspan 0001:00.0 1.00000 1.00000 8 00:01:10.0 Offset 15 9 00:01:20.0 -0.4 35 Datatype 00:01:30.0 -0.4 63 Lower Upper Units PSI G PSI G PSI G PSI G Tare Average User Factor User Offset User Resolution Firmware Version R080015 R090009 R090009 Calibration Due 25-Feb-17 25-Aug-17 Run Index 0 Run Start Time 2-Oct-18/11:31:22 Run Duration 41 minutes 50 seconds Run Tag 21 b-16 10-2-18 11-ogging Interval 1 10.0 ata Points Point # Time Left - PSI G Right - PSI G "I UU:uu:uu.0 -U.4 -Y 2 00:00:10.0 -0.4 1 3 00:00:20.0 -0.4 -1 4 000030.0 -0.4 -1 5 00:00:40.0 -0.4 -1 6 00:00:50.0 -0.4 -1 7 0001:00.0 -0.4 4 8 00:01:10.0 -0.4 15 9 00:01:20.0 -0.4 35 10 00:01:30.0 -0.4 63 11 00:01:40.0 -0.4 97 12 00:01:50.0 -0.4 132 13 00:02:00.0 -0.4 169 14 00:02:10.0 -0.4 206 15 00:02:20.0 -0.4 243 16 00:02:30.0 -0.4 280 17 00:02:40.0 -0.4 318 18 00:02:50.0 -0.4 356 19 00:03:00.0 -0.4 394 20 00:03:10.0 -0.4 433 21 00:03:20.0 -0.4 472 22 00:03:30.0 -0.4 510 23 00:03:40.0 -0.4 550 24 00:03:50.0 -0.4 589 25 00:04:00.0 -0.4 628 26 00:04:10.0 -0.4 667 27 00:04:20.0 -0.4 706 28 00:04:30.0 -0.4 746 29 00:04:40.0 -0.4 784 30 00:04:50.0 -0.4 824 31 00:05:00.0 -0.4 863 32 00:05:10.0 -0.4 902 33 00:05:20.0 -0.4 941 34 00:05:30.0 -0.4 980 35 00:05:40.0 -0.4 1019 36 00:05:50.0 -0.4 1058 37 00:06:00.0 -0.4 1097 38 00:06:10.0 -0.4 1136 39 00:06:20.0 -0.3 1174 40 00:06:30.0 -0.4 1213 41 00:06:40.0 -0.4 1253 42 00:06:50.0 -0.4 1291 43 00:07:00.0 -0.4 1329 44 00:07:10.0 -0.4 1368 45 00:07:20.0 -0.4 1406 46 00:07:30.0 -0.4 1445 47 00:07:40.0 -0.4 1484 48 00:07:50.0 -0.5 1522 49 00:08:00.0 -0.4 1560 50 00:08:10.0 -0.4 1598 51 00:08:20.0 -0.4 1637 52 00:08:30.0 -0.4 1674 53 00:08:40.0 -0.4 1713 54 00:08:50.0 -0.4 1751 55 00:09:00.0 -0.4 1790 56 00:09:10.0 -0.4 1827 57 00:09:20.0 -0.4 1865 58 00:09:30.0 -0.4 1903 59 00:09:40.0 -0.4 1941 60 00:09:50.0 -0.4 1978 61 00:10:00.0 -0.4 2015 62 00:10:10.0 -0.4 2051 63 00:10:20.0 -0.4 2081 64 00:10:30.0 -0.4 2083 65 00:10:40.0 -0.4 2080 66 00:10:50.0 -0.4 2079 67 00:11:00.0 -0.4 2078 68 00:11:10.0 -0.5 2078 69 00:11:20.0 -0.4 2078 70 00:11:30.0 -0.5 2077 71 00:11:40.0 -0.4 2076 72 00:11:50.0 -0.4 2075 73 00:12:00.0 -0.4 2075 74 00:12:10.0 -0.4 2074 75 00:12:20.0 -0.4 2073 76 00:12:30.0 -0.4 2074 77 00:12:40.0 -0.4 2073 78 00:12:50.0 -0.4 2072 79 00:13:00.0 -0.4 2072 80 00:13:10.0 -0.3 2071 81 00:13:20.0 -0.4 2070 82 00:13:30.0 -0.4 2070 83 00:13:40.0 -0.4 2069 84 00:13:50.0 -0.4 2069 85 00:14:00.0 -0.4 2068 86 00:14:10.0 -0.4 2068 87 00:14:20.0 -0.4 2067 88 00:14:30.0 -0.4 2067 89 00:14:40.0 -0.4 2067 90 00:14:50.0 -0.4 2066 91 00:15:00.0 -0.4 2066 92 00:15:10.0 -0.4 2065 93 00:15:20.0 -0.4 2065 94 00:15:30.0 -0.4 2064 95 00:15:40.0 -0.4 2064 96 00:15:50.0 -0.4 2063 97 00:16:00.0 -0.4 2063 98 00:16:10.0 -0.4 2062 99 00:16:20.0 -0.4 2062 100 00:16:30.0 -0.4 2062 101 00:16:40.0 -0.4 2061 102 00:16:50.0 -0.4 2061 103 00:17:00.0 -0.4 2060 104 00:17:10.0 -0.4 2060 105 00:17:20.0 -0.4 2059 106 00:17:30.0 -0.4 2059 107 00:17:40.0 -0.4 2059 108 00:17:50.0 -0.4 2058 109 00:18:00.0 -0.4 2058 110 00:18:10.0 -0.4 2057 111 00:18:20.0 -0.4 2057 112 00:18:30.0 -0.4 2057 113 00:18:40.0 -0.4 2056 114 00:18:50.0 -0.4 2056 115 00:19:00.0 -0.4 2055 116 00:19:10.0 -0.4 2055 117 00:19:20.0 -0.4 2055 118 00:19:30.0 -0.4 2054 119 00:19:40.0 -0.4 2054 120 00:19:50.0 -0.4 2053 121 00:20:00.0 -0.4 2053 122 00:20:10.0 -0.4 2053 123 00:20:20.0 -0.4 2052 124 00:20:30.0 -0.3 2052 125 00:20:40.0 -0.4 2052 126 00:20:50.0 -0.4 2051 127 00:21:00.0 -0.4 2051 128 00:21:10.0 -0.4 2050 129 00:21:20.0 -0.3 2050 130 00:21:30.0 -0.4 2050 131 00:21:40.0 -0.4 2049 132 00:21:50.0 -0.4 2049 133 00:22:00.0 -0.4 2048 134 00:22:10.0 -0.4 2048 135 00:22:20.0 -0.4 2048 136 00:22:30.0 -0.4 2047 137 00:22:40.0 -0.4 2047 138 00:22:50.0 -0.4 2047 139 00:23:00.0 -0.4 2046 140 00:23:10.0 -0.4 2046 141 00:23:20.0 -0.4 2045 142 00:23:30.0 -0.4 2045 143 00:23:40.0 -0.4 2045 144 00:23:50.0 -0.4 2044 145 00:24:00.0 -0.4 2044 146 00:24:10.0 -0.4 2044 147 00:24:20.0 -0.4 2043 148 00:24:30.0 -0.4 2043 149 00:24:40.0 -0.4 2043 150 00:24:50.0 -0.4 2042 151 00:25:00.0 -0.4 2042 152 00:25:10.0 -0.4 2042 153 00:25:20.0 -0.4 2041 154 00:25:30.0 -0.4 2041 155 00:25:40.0 -0.4 2040 156 00:25:50.0 -0.4 2040 157 00:26:00.0 -0.4 2040 158 00:26:10.0 -0.4 2040 159 00:26:20.0 -0.4 2039 160 00:26:30.0 -0.4 2039 161 00:26:40.0 -0.4 2038 162 00:26:50.0 -0.4 2038 163 00:27:00.0 -0.4 2038 164 00:27:10.0 -0.4 2037 165 00:27:20.0 -0.4 2037 166 00:27:30.0 -0.4 2037 167 00:27:40.0 -0.3 2036 168 00:27:50.0 -0.4 2036 169 00:28:00.0 -0.4 2036 170 00:28:10.0 -0.4 2035 171 00:28:20.0 -0.4 2035 172 00:28:30.0 -0.4 2035 173 00:28:40.0 -0.4 2034 174 00:28:50.0 -0.4 2034 175 00:29:00.0 -0.4 2034 176 00:29:10.0 -0.4 2033 177 00:29:20.0 -0.4 2033 178 00:29:30.0 -0.4 2033 179 00:29:40.0 -0.4 2032 180 00:29:50.0 -0.4 2032 181 00:30:00.0 -0.4 2031 182 00:30:10.0 -0.4 2031 183 00:30:20.0 -0.4 2031 184 00:30:30.0 -0.4 2030 185 00:30:40.0 -0.4 2030 186 00:30:50.0 -0.4 2030 187 00:31:00.0 -0.4 2029 188 00:31:10.0 -0.4 2029 189 00:31:20.0 -0.4 2029 190 00:31:30.0 -0.4 2028 191 00:31:40.0 -0.4 2028 192 00:31:50.0 -0.4 2028 193 00:32:00.0 -0.4 2028 194 00:32:10.0 -0.4 2027 195 00:32:20.0 -0.4 2027 196 00:32:30.0 -0.4 2026 197 00:32:40.0 -0.4 2026 198 00:32:50.0 -0.4 2026 199 00:33:00.0 -0.4 2026 200 00:33:10.0 -0.4 2025 201 00:33:20.0 -0.4 2025 202 00:33:30.0 -0.4 2024 203 00:33:40.0 -0.4 2024 204 00:33:50.0 -0.4 2024 205 00:34:00.0 -0.5 2024 206 00:34:10.0 -0.4 2023 207 00:34:20.0 -0.4 2023 208 00:34:30.0 -0.4 2023 209 00:34:40.0 -0.3 2022 210 00:34:50.0 -0.4 2022 211 00:35:00.0 -0.4 2022 212 00:35:10.0 -0.3 2021 213 00:35:20.0 -0.4 2021 214 00:35:30.0 -0.4 2021 215 00:35:40.0 -0.4 2020 216 00:35:50.0 -0.4 2020 217 00:36:00.0 -0.4 2020 218 00:36:10.0 -0.4 2020 219 00:36:20.0 -0.4 2019 220 00:36:30.0 -0.4 2019 221 00:36:40.0 -0.3 2019 222 00:36:50.0 -0.4 2018 223 00:37:00.0 -0.4 2018 224 00:37:10.0 -0.4 2017 225 00:37:20.0 -0.4 2017 226 00:37:30.0 -0.4 2017 227 00:37:40.0 -0.4 2016 228 00:37:50.0 -0.4 2016 229 00:38:00.0 -0.4 2016 230 00:38:10.0 -0.4 2015 231 00:38:20.0 -0.4 2015 232 00:38:30.0 -0.4 2015 233 00:38:40.0 -0.4 2015 234 00:38:50.0 -0.4 2014 235 00:39:00.0 -0.4 2014 236 00:39:10.0 -0.4 2014 237 00:39:20.0 -0.4 2013 238 00:39:30.0 -0.4 2013 239 00:39:40.0 -0.4 2013 240 00:39:50.0 -0.4 2012 241 00:40:00.0 -0.4 2012 242 00:40:10.0 -0.4 2012 243 00:40:20.0 -0.4 2011 244 00:40:30.0 -0.4 2011 245 00:40:40.0 -0.4 2011 246 00:40:50.0 -0.4 2010 247 00:41:00.0 -0.4 2010 248 00:41:10.0 -0.4 2010 249 00:41:20.0 -0.4 2009 250 00:41:30.0 -0.4 2009 251 00:41:40.0 -0.4 2009 252 00:41:50.0 -0.4 2007 Con Lbrtg Inc McLANE Well S.C.U. 21 B-16 Plug & Abandon Memo Via email Date: 25 October 2018 To: Hilcorp Alaska LLC....................................................Attn: Cole Bartlewski From: Stan A. McLane, PLS Project: Swanson River Unit— SCU 21B-16 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Swanson River Unit SCU 21B-16 well located in Section 16, T7N, R9W Seward Meridian, Alaska. The survey was performed on October 25, 2018. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was confirmed by comparing (2) check shots on hard targets to existing data. To establish original ground elevation near the well casing, (2) survey measurements were observed at the perimeter of the pad in opposite positions from the well location. These elevations were compared to contours and reflect the pad is positioned on a natural bench. The higher side was held and assumed to fairly represent original ground in the absence of historical data. A top of pad elevation was also recorded adjacent to the well casing then a reference grade stake was set with measurements to the proposed cutoff elevation from an X on top of cellar. Enclosed is Exhibit A which includes pad asbuilt data from 2018 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 145.5' ± (2018) • Original ground elevation in vicinity of well casing: 145.4' ± (2018) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 142.4' • Casing cutoff elevation as staked in field: 141.4' The cutoff mark elevation of 141.4', as referenced in the field, exceeds the required minimum cutoff elevation of 142.4'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email SaMclane@mclaneg.com Co uffing Inc KjcLANE Please feel free to contact me if you have any questions or comments. Sincerely, Stan A. McLane, PLS McLane Consulting, Inc. 0F,A4,gS#t 49 v * IH00� 00 o STAN 0. McLANE r II 46 7—S Page 2 of 2 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email SaMclane@mclaneg.com / J NORTH ! I \ 1 11 ORIGINAL GROUND SHOT( ELEV = 142.8 (2018) l / 1 \\llljl 011 X1111 VIII 111 1 III I VIII llIJI ll/1 11)It1�\ i / / I I, L I l/ 1 I I J J 3 � 1 a w z L0 o� o>/ Q JI CL KLJ, II ®I SCU 21B-16 P&A ASP NAD83, ZONE 4 N: 2,449,808.2 E: 1,484,302.9 ELEV = 145.5 GRAPHIC SCALE 0 30 60 120 NOTES 1 inch = 60 ft. 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2458384.578 1 E = 1483669.444 1 ELEV. = 212.690 (NAVD88) 1 1 l 0 (ORIGINAL !GROUND SHOT 11 1 ELEV = 145-7 (2018) I VIII WELL CASING CUT—OFF DETAIL WELL CASING j -'TO BE REMOVED I I PAS FI FV = 145.5' t i 4.0' i O.G. ELEV = 145.4' t REFERENCED WELL CASING CUTOFF AT 3L'iZA! Comffin Irk PROJECT HILLCORP ALASKA, LLC SWANSON RIVER FIELD RMSION: 1 DATE: W1)I19 DRAWN BY JAH 3 I J / ( I PLUG AND ABANDON EXHIBIT -A SCALE'. NO PROJECT N0. 187035 ENGINEERING I MAPPING I SURVEYING I TESTING NAD 83, ASP ZONE 4 BOOKNO. 1847 LOCATIgJ SECTION 16, T7N, R9W SEWARD MERIDIAN, ALASKA GRAPHIC SCALE 0 30 60 120 NOTES 1 inch = 60 ft. 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2458384.578 1 E = 1483669.444 1 ELEV. = 212.690 (NAVD88) 1 1 l 0 (ORIGINAL !GROUND SHOT 11 1 ELEV = 145-7 (2018) I VIII WELL CASING CUT—OFF DETAIL WELL CASING j -'TO BE REMOVED I I PAS FI FV = 145.5' t i 4.0' i O.G. ELEV = 145.4' t REFERENCED WELL CASING CUTOFF AT 3L'iZA! Comffin Irk PROJECT HILLCORP ALASKA, LLC SWANSON RIVER FIELD RMSION: 1 DATE: W1)I19 DRAWN BY JAH 3 WELL SCU 21B-16 PLUG AND ABANDON EXHIBIT -A SCALE'. NO PROJECT N0. 187035 ENGINEERING I MAPPING I SURVEYING I TESTING NAD 83, ASP ZONE 4 BOOKNO. 1847 LOCATIgJ SECTION 16, T7N, R9W SEWARD MERIDIAN, ALASKA SHEET PO. BOX 488 SOLDOTNA, M. 98888 VOICE: (85]Iz834318 FA �."RB&3388 EMNL: SAMCLANE®MCLNIECGCAM Hiloorp Alaska, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1\ l �� 1 71, y DATE: August 281h 2019 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandon Petroleum Inspector SCU 21B-16 Hilcorp Alaska Inc. PTD 1852550; Sundry 318-314 8/26/2019: 1 arrived at Swanson River Field and met with Mike Erstrom (Hilcorp Construction Foreman). We went to the well location and I verified there was good hard cement to surface and all the correct information was on the marker plate. The cut off is over 4 feet below grade. I also took pictures of the hard cement, marker plate, marker plate after welded on and the depth of the cutoff. Attachments: Photos (4) 2019-0826_Surface_Abandon_SCU_21B-16_bb.docx Page 1 of 3 I ail W- a 1A a ' 7�y •� 44',�A6 F -w� 'r r A j i��q. S 44',�A6 F 'r k,., 4, . �� • . Y 4k r a or" ,��, _A,7,-0ice, ' 2019-0826_Surface_Abandon_SCU_21 B-16_bb.docx Page 3 of 3 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_~.~ Well History File Identifier Organization (done) [J~Two-Sided RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: I'eT[ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL~ LOWELL Project Proofing :[3 OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds E3 Other [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl (at the time of scanning) SCANNED BY; BEVERLY BREN VlNCE~ARIA LOWELL RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) RevINOTScann~:I.Y4xI ~ UNOCALe -Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com August 31, 2005 ¢" \ lÖÇ~ '). Commissioner John Norman AOGCC 333 w. th Avenue, Ste 100 Anchorage, AK 99501 ¡~::~~ ~:t;::'t.~.l~ SEP G 6 2005 Re: Subsequent SCU 218-16 Commissioner Norman: Our records indicate that a subsequent report for sundry 302-255 (SCU 218-16) was not filed with the AOGCC. Please see the enclosed for 10-404 to bring this well work up-to-date. I apologize for the tardiness of this filing. Please contact me at 263-7657 if you have any questions. Sincerely, -? (5:"'~ ,..-·..··"7 -~~.'Q /"':-. J ( ..~ '-...... .. C 6;:?') Timothy C~ndenburg Drilling Manager ¿::;;;?' .~ -'" 1t.:(r-i/¡...b"'~~'l.iE-T¡ roE- 0 \1 f.) ?OOr. 1\~'~M""1.\nß\'· _) .J.J t 0 I- .. ,J Attachments Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com STATE OF ALASKA " ALAs{ OIL AND GAS CONSERVATION COMrv~ JION REPORT OF SUNDRY WELL OPERATIONS V""'}, f,'''- ~l", ~::~, tf:: ,~~ lf ~~~ ~~~~\ I! ";~,¡\', ,,,, M I~ I~." ~ \\! ,:~ j¡"..J 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate U Ot~f LP S ~Q~Plete Waiver D 1ð"rt!~; Æ!fta1~~sm!EI:. Re-enter Suspended Wel~tJ~ 5. Permit to Drill Nû'mDe1: ExploratoryD 185-255 ServiceD 6. API Number: 50-133-10132-02 9. Well Name and Number: SCU 21B-16 10. Field/Pool{s): Swanson River Field/Hemlock I~ Dfr;,t~'~j~ ~~C n 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing 0 Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 7. KB Elevation (ft): 168' RKB above MSL 8. Property Designation: Swanson River Field 11. Present Well Condition Summary: Total Depth measured 11,004' feet true vertical 10,998 feet Effective Depth measured 7,750' feet true vertical 7,748' feet Casing Length Size MD Structural Conductor 35' 22" 55' Surface 2,035' 11-3/4" 2,035' Intermediate Production 11,023' 7" 11,023' Liner 2,301' 5" 11,004' Perforation depth: Measured depth: 6,524' to 10,714' Plugs (measured) 7,750' Junk (measured) TVD Burst Collapse 54' 2,034' 3,070 psi 1,510 psi 11,017' 6,430 psi 3,830 psi 10,998' 10,140 psi 10,190 psi True Vertical depth: 6,523' to 10,709' Tubing: (size, grade, and measured depth) 2-7/8" L-80 to 6,360' Packers and SSSV (type and measured depth) Retrievable Baker Packer @ 6,166' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a RBDMS BFL SEP 0 8 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10 27 800 000 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 7 o Tubing Pressure 400 o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 302-255 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg -"/ '7 _.-Z:;~ /' /f r·'../ Signature ~L-¡:) 7 Form 10-404 Revised 04/2004 p Title Drilling Manager Phone 907-276-7600 Date 8/18/2005 AFE 156405 Submit Original Only UNOCALe 7" Squeezed W 1500sx @ 212' PT to 3000 psi Tight in Casing @6,652' WI 6" Bit DV Tool @ 7,794' Cemented wi I ,200sx seD 21B-16 RKB = 20' 1 .~ \ \ "1 ì :11 .~ î ( ~ 3. 4 z::~ 2 5 6 ~ x D A~ [ ;! ] .¡ 7 'I I j ~'\".,,! f · I U S g L 8 9 10 I ¡ Ëf,"."" .!,,~ ,I .~ 11 >< / 8 ~ H2 = H3 H5 ~ Swanson River Well SCD 21B-16 Actual Completion CASING AND TUBING DETAIL SIZE "T GRADE CONN ID TOP BTM. 22" 36' 11-3/4" 47 J-55 S8R Surtàce 2,035' T' 29 N-80 Butt 6.184 Surface 81 ' 7" 23 N-80 Butt 6.366 81' 4,821 ' 7" 26 N-80 L8R 6.276 4,821' 6,744' 7" 29 N-80 L8R 6.184 6,744' 7,793' DV L8R 7,793' 7,796' 7" 29 N-80 L8R 6.184 7,796' 8,564' 7 29 P-110 L8R 8,564' 8,704 ' 5" 18 N-80 SCC Butt 4.151 8,704' 11,004' Tubing 2- 7/8" 6.4 L-80 2.441 6,360' JEWELRY DETAIL NO. Depth ID OD Item 1 Tubing Hanger, 3-] /2" 2 2,000' Methano] Injection Mandre], 3- ]/2" 3 6,129' GLM, 3-1/2" Dummied 4 6,166 ' Packer, Baker Retrievab]e, 3-] /2" x 7" 5 6, ] 91' X-Nipple, 3-1/2", 2.813" 10 6 6,230' WLEG,2.813 A 7,750' 7" Bridge Plug 7 8,569' Crossover, 3-112" x 2-3/8" 8 10,270' GLM, 2-3/8" Merla 'TMPDX' 9 10,301' 1.875 S-Nipp1e, 2-3/8" 10 10,341 ' 4.00 Gravel Pack Packer, Baker, SC-1L II 10,364' Shear Out Safety Joint, 2-3/8", Baker 12 10,604 ' Grave] Pack Screens, 2-3/8" 13 10,740' Sump Packer, Baker DB Perforation Record Date Zone !ill! Bottom Amount Accum Item SPF 64-5 6,524' 6,554' 34 4 Perforations H-2 ]0,606' 10,628' 22' 14 Abandoned H-3 10,644 ' 10,665 ' 21 ' ]4 Abandoned H-5 10,684 ' 10,714' 30' 14 Abandoned PBTD = 10,960', TD = 11,005' MAX HOLE ANGLE = 4deg @9300' Revised by DED as of 9/24/02 8/26/02 P/U injector and M/U BHA. Test BOP to 25013000 psi. Load coil with water and body test tree and stack. GIH with CT to 10,600' while reducing tubing, and tubing X 7" annulus, pressure, from 1200 psi to 1010 psi. Mix and pump 12 bbls of 15.8 ppg cement. As cement reached EDT, began POOH displacing well bore 1 for 1 with cement, and also bleeding pressure to keep annulus near 1000 psi. CIP at 16:30 hrs. 8-26-02. POOH with pumps off. Annulus pressure dropped from 1060 psi to 1015 psi. ETOC, with no losses = 8109'. Secure well. Circulate thru and clean coil. RID injector head and pump coil dry with nitrogen. RID remaining equipment, but keeping same on location for possible second job. 8/27/02 PJSM. Spot Pollard equipment. RlU lubricator and 1.5" OD slickline tools with 1.75" blind box on bottom. Open well with 1000 psi SITP. GIH and tag hard cement at 9042' WLM. POOH. Secure well. RID wireline equipment. 8/28/02 Check well pressures - SITP = 1000 psi, CP = 1000 psi. Attempt to close casing valve and bleed pressure off gauge. Valve not holding. Greased casing valve, tree valves and flowlinevalves. R/U pump truck on tubing and test line to 1300 psi. Bullhead 120 bbls down tubing wi final pressure 1200 psi. Casing pressure 1700 psi. Shut down with SITP = 500 psi, CP = 1700 psi. Will let water fall and pressure stabilize over night. 8/29/02 R/U bleed off line wi choke to Johnson tank. Bled gas off casing to 400 psi. SITP = 300 psi. Pump down tubing w/130 bbls taking returns on casing to Johnson tank holding 400 psi on casing. Oil back to surface with 1,3'0 bbls pumped. Bled casing to 0 psi. SITP = 0 psi. Continued circulating 50 bbls oil off backside until clean water back. Shut down and monitor tubing and casing - static. RD pump line and return line. 9/18/02 Rig assigned to SCU 21 B-16 at 0600 hrs. 9-18-02.RU. Began BOP tests. Repaired several leaks with final leak determined to be thru casing hanger to annulus. Notified Unocal personnel and Tom Maunder w/AOGCC. Decision made to test BOP against closed annulus to 750 psi. Pressure up on BOP and 7" casing to 800 ,psi. Observed for 15 min on chart, tested ok. Pulled on tubing and unseated tubing hanger'with 78000# (string weight @ 58000#). Broke off and laid out tubing hanger and 4' pup jt. Tubing hanger seals appeared to have been damaged when tubing was originally landed. Possibly with lock down screws screwed in damaging both seals (Top seal completely cut). Picked up new tubing hanger and crossover subs. Landed tubing in tubing head with no problem. Screwed in lock down screws. Rigged up to test BOPE. 9/19/02 Tested all BOPE to 25013000 psi, ok. RD BOPE. Pull 2-way check. Pre-job safety meeting and service rig. Picked up on tubing and pulled tubing hanger to rig floor with no problem. LD tubing hanger. LD 3-1/2" tubing. LD total of 245 jts. Plus 1 cut joint. Total of 245 jts & 12' cut jt. Found only 1 hole at +1- 4460'. RU Schlumberger. Ran 5.875" OD junk basket gauge ring with GR/CCL to 6610' with no problem. Logged up to 5500' with GR/CCL. POOH with logging tool and laid down same. Picked up a Baker 7" 29# CIBP and ran in hole. Set CIBP at 6590' with no problem. Pooh with wireline. RD Schlumberger. RU rig pump and chart recorder to test 7" casing. Installed gauges on 7" casing valve and 7" x 9-5/8" casing annulus. Repaired a small leak on rig stand pipe. Tested 7" casing to 2500 psi for 15 min, ok. Bled off pressure. Load 3-1/2" tubing onto pipe racks and measure as loaded. 9/20/02 Picked up a Baker Mule shoe sub with pump out plug set at 3,300 psi, 1 jt 3-1/2" 9.3#, L-80 Imp BTC tubing with special clearance coupling, Baker "X" Nipple with 2.813" profile, 1 jt of 3-1/2" tubing, Baker 84 SAB 40 x 32 permanent packer and KBH anchor seal assembly, 1 jt 3-1/2" tubing, GLM. GIH with 130 jts 3 1/2" 9.3# 1-80 BTC tubing. P/U 31/2" Macco SMO-1CI chemical injection mandrel. Install injection line and test to 1400 psi. GIH with tubing, maintaining 1000 psi on line and testing line to 1400 psi every 500'. Install 3 SS bands per joint. End of SRU 21 B-16 (156405) morning report summary, CONFIDENTIAL: last revised 8/26/2005, Page 1. " t tubing at 6,569'. Total tubing in hL...... at this point 207 jts. Rigged up to circulate èmd displace well. Spotted 400 bbl Johnson tank for returns and hooked up same. Circulate and displace well with 263 bbls of 8.8 ppg 9% Kcl water at 2.0 bpm with max pressure at 200 psi. Calculated hole volume at 223 bbls. Shut down pump and rigged down circulating equipment. 9/21/02 Laid down 11 jts of 3-1/2" tubing. Have 206 total SS Bands in hole at this point. Picked up tubing hanger with 4.09' pup jt. Installed 3/8" SS control line to top and bottom of tubing hanger. RIH and landed tubing in tubing head with 39,000 # on hanger. Test control line by pumping valve open, ok. Ran in lock down screws on tubing head. Rigged up lines to reverse circulate. Pumped 5 bbls of diesel down production casing annulus (freeze protection). Rigged down reversing lines. Removed TIW valve. Dropped 2.00" OD packer setting ball and allowed to fall. Pressured up to 2000 psi and initiated packer setting sequence. Hold for 15 min. Pressure up to 3,800 psi and shear ball seat. Tested tubing and packer to 2,500 psi for 10 min. Test annulus to 1500 psi for 10 min. Install 2 way check and NID BOPs, choke manifold and hoses. NU 7 1/16" 5M tree with CIW 3" type "H" BPV profile. Test to 5000 psi. Remove 2 way check. Released rig to Nabors for rigging down at 14:30 hrs 9-21-02. 9/23/02 Remove flowline for extension. Rigged up test manifold and Johnson tank. Installed Bowen wireline flange on tree top. Hooked up chemical injection pump. Loaded out and returning rental equipment. 9/24102 R/U Pollard wireline and test lubricator to 2000 psi. Begin swabbing with 2.87" OD swab cups at 200'. Swab to 1530'. Recovered 13.3 bbls fluid. RD Pollard. RU Schlumberger. Test lubricator to'5000 psi. GIH w 2 1/2" 6 spf, 60 deg. phasing, power jet gun and perforate 6,524'-6,554' as per GR-CCL log dàted 9-19-2002. No increase in SITP after shots fired. RD Schlumberger. Well turned over to production @ 23:00 hrs. SRU 21B-16 (156405) morning report summary, CONFIDENTIAL: last revised 8/26/2005, Page 2. Subject: Re: SCU 21B-J6--PTD 185-255 Date: Tue, 17 Sep 2002 07:55:36 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Brandenburg, Tim C -Contract" <brandenburgt@unocal.com > Tim, your proposal makes sense. of this message in the file. Tom Maunder, PE AOGCC I do not believe these changes require submitting another sundry. I will place a copy "Brandenburg, Tim C -Contract" wrote: Tom,We are about to move to our last planned well at Swanson River, Well SCU 21B-16 which we have an approved 10-403 for. In the original procedure submitted with the Sundry, I have us setting a bridge plug at 7750' (Above the DV tool at 7794'). I have recently found were they discovered a tight spot in 1985 with a 6-1/8" stabilizer in the 6.276" I.D. casing at 6605'. As such, I would like to move the bridge plug above the spot and set it at approx 6575'. The well has integrity, but I do not want to place excessive differential on this area of the casing stdng when we are depleting the gas sands above. Also, Unocal now plans to run 3-1/2" tubing. Do I need to submit a new 10.403 to the Commission for these changes?Thanks for the assistance,Tim Tom Maunder <tom maunder@admin.state.ak.us> Sr, Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 9/17/2002 7:55 AM STATE OF ALASKA ALASKA O'T L AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved Program: Pull tubing: X Variance: X Perforate: Other: X Re-complete 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 168' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 ~. Service: Soldotna Creek Unit 4. Location of well at surface ~/~- ,/' 8. Well number 657' FNL, 1985' FWL, Sec. 16, T7N, R9W, SM SOU 21B-16 At top of productive interval 9. Permit number 185-255 At effective depth 10. APl number 50- 133-101321-02 V/ At total depth 11. Field/Pool 441' FNL, 1906' FWL, Sec. 16, T7N, Rgw, SM Swnason River Field / Hemlock 12. Present well condition summary Total depth: measured 11,004'*/ feet Plugs (measured) true vertical feet Effective depth: measured 10,772' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 35' 22" 55' 55' Surface 2,035' 11-3/4" 1,600 sx 2,035 2,035' Intermediate Production 11,023' 7" I stg 600 ex, 1,200 sx @ DV 11,045' 11,045' Liner 2,301' 5" 275 sx 11,004' 11,000' Perforation depth: measured 10,606'-10,628'; 10,644'-10,655'; 10,684'-10,714' true vertical 10,601'-10,623'; 10,639'-10,660'; 10,679'-10,709' Tubing (size, grade, and measured depth) 3-1/2", J-55 to 8,569', 2-3/8', N-80 to 10,740' Packers and SSSV (type and measured depth) SCl L Gravel Pack Packer 10,341'; Baker DB Sump Packer @ 10,740' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 8/19/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. q ~) FOR COMMISSION USE O~LY Conditions of approval: Notify Commission so representative may witness ~~ ~,~ ~;)O'~ ~~~Apl:~val No. Plug integrity BOP Test Location clearanceIl ~ O2" 2.-'~ 5 Mechanical Integrity~~Test Subsequent form required 10- -L.~ ~ ~ ^ Alaska 0ii & 0ng,nal S~gned BY Anchorage ~ ~.~., Approved by order of the Commissioner Camffl¥ Oechsli Tay~ '" - _ Commissioner Date . Form 10-403 Rev 06/15/88 0RIG!i AL SUBMIT iN TRIPLICATE Unocal Alaska Soldotna Creek Unit Well No. SCU 21B-16 Abandon andf Re-complete UNOCAL~ No. Preliminary Procedure Prep Well/Abandon Hemlock Recover Center Set Valves with Slicldine RU 1-1/2" Coiled Tubing. Lay Hemlock Abandonment plug from 10,604' (Top of Screens) to 9000' (1600 lineal feet = 9.25 bbls) of 15.8ppg Cement. 5" Cpacity from PBTD to SCl-Packer = 7.5 bbls not including Screen and sand Displacment. POOH with CT. RD Coiled Tubing. Fill well with fluid. -- c-O3~ ~L,~'X~,~ 1 Vo'~%%~--rc ~-_~'~ ~Qk~t~o~ :Workover ~ ~ 1 MIRU Pulling Unit 2 ND Tree, NU BOP and Test 3 POOH standing back 3-1/2" and 2-3/8" tubing LD punched Jts. 4 Set retainer at 7750' (above DV Tool). 5 Lay Down 3-1/2" and 2-3/8" tubing. 6 Run 2-3/8" Completion to 6300' 7 Set packer, land tubing. 8 ND BOP's. 9 NU Tree, Test. 10 RD Workover Rig SCU 21B-16 ABDN Attach.xls Page 1 of 1 8/12/02 UNOCAL ) Tight in Casing @6,652' W/ 6" Bit DV Tool ~ ?,794' 4 Cemented w/ 1,200sx 5 SIZE WT Swanson River Well SCU 21B-16 Actual Completion CASING AND TUBING DETAIL GRADE CONN ID 11-3/4" 47 J-55 S8R 7" 29 N-80 Butt 7" 23 N-80 Butt 7" 26 N-80 L8R 7" 29 N-80 LSR DV L8R 7" 29 N-80 L8R 7 29 P-110 L8R 5" 18 N-80 SCC Butt Tubing 3-1/2" 9.3 J-55 2-3/8" 4.6 N-80 NO. Depth 1 2 3 4 5 6 7 8 9 10 11 12 4,474' 6,304' 7,936' 8,569' 9,289' 10,270' 10,307' 10,341' 10,364' 10,604' 10,740' 1.875 4.00 TOP 6.184 6.366 6.276 6.184 6.184 4.151 2.991 1.995 Surface Surface 81' 4,821' 6,744' 7,793' 7,796' 8,564' 8,704' 8,569' Date Zone Top JEWELRY DETAIL OD Item H-2 10,606' H-3 10,644' H-5 10,684' Tubing Hanger Center Set Valve Center Set Valve Center Set Valve Crossover, 3-1/2" x 2-3/8" Center Set Valve GLM, 2-3/8" Merla 'TMPDX' S-Nipple, 2-3/8" Gravel Pack Packer, Baker, SC-1L Shear Out Safety Joint, 2-3/8", Baker Gravel Pack Screens, 2-3/8" Sump Packer, Baker DB Perforation Record Bottom Amount Accum SPF Item 10,628' 22' 14 10,665' 21' 14 10,714' 30' 14 Gravel Packed Gravel Packed Gravel Packed BTM. 36' 2,035' 81' 4,821' 6,744' 7,793' 7,796' 8,564' 8,704' 11,004' 8,569' 10,341' H2 H3 10 H5 SCU 21B-16 Act Draw PBTD = 10,960', TD = 11,005' MAX HOLE ANGLE = 4deg ~9300' DRAWN BY: tcb REVISED: 7/31/02 UNOCALe Tight in Casing @6,652' W/ 6" Bit DV Tool ~ 7,794' Cemented w/ 1,200sx A 6 10 SCU 21B-16 Prop Abdn Draw SIZE Swanson River Well SCU 21B-16 Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 11-3/4" 47 J-55 S8R 7" 29 N-80 Butt 7" 23 N-80 Butt 7" 26 N-80 LSR 7" 29 N-80 LSR DV L8R 7" 29 N-80 LSR 7 29 P-110 L8R 5" 18 N-80 SCC Butt Tubing 3-1/2" 9.3 J-55 2-3/8" 4.6 N-80 6.184 6.366 6.276 6.184 6.184 4.151 2.991 1.995 Surface Surface 81' 4,821' 6,744' 7,793' 7,796' 8,564' 8,704' 8,569' 36' 2,035' 81' 4,821' 6,744' 7,793' 7,796' 8,564' 8,704' 11,004' 8,569' 10,341' NO. Depth ID JEWELRY DETAIL OD Item A 6 7 8 9 10 11 12 7,750' 8,569' 10,270' 10,307' 10,341' 10,364' 10,604' 10,740' 1.875 4.00 7" Retainer Crossover, 3-1/2" x 2-3/8" GLM, 2-3/8" Merla 'TMPDX' S-Nipple, 2-3/8" Gravel Pack Packer, Baker, SC-IL Shear Out Safety Joint, 2-3/8", Baker Gravel Pack Screens, 2-3/8" Sump Packer, Baker DB Date Zone Top Perforation Record Bottom Amount Accum SPF Item H-2 10,606' H-3 10,644' H-5 10,684' 10,628' 22' 10,665' 21' 10,714' 30' 14 Proposed Abandon 14 Proposed Abandon 14 Proposed Bandon H2 H3 H5 PBTD = 10,960', TD = 11,005' MAX HOLE ANGLE = 4deg ~9300' DRAWN BY: tcb REVISED: 12/21/98 UNOCAL SX~E 22" 11-3/4" 7" 7" 7" 7" DV 7" 7 5" Tubing 2-7/8" Swanson River Well SCU 221B-16 Proposed Completion CASING AND TUBING DETAIL GRADE CONN ID TOP 47 29 23 26 29 29 29 18 6.4 J-55 S8R Surface N-80 Butt 6.184 Surface N-80 Butt 6.366 81' N-80 L8R 6.276 4,821' N-80 LSR 6.184 6,744' L8R 7,793' N-80 L8R 6.184 7,796' P-110 L8R 8,564' N-80 SCC Butt 4.151 8,704' L-80 2.441 BTM. 36' 2,035' 81' 4,821' 6,744' 7,793' 7,796' 8,564' 8,704' 11,004' 6,360' Tight in Casing ~6,652' W/ 6" Bit DV Tool ~ 7,794' Cemented w/ 1,200sx 4 5 7 8 9 10 SCU 21B-16 Prop Draw H2 H3 H5 NO. Depth JEWELRY DETAIL OD Item A 6 7 8 9 10 11 12 2,000' 6,300' 6,330' 6,360' 7,750' 8,569' 10,270' 10,307' 10,341' 10,364' 10,604' 10,740' 1.875 4.00 Tubing Hanger, 2-7/8" Methanol Injection Mandrel Packer, Baker Retrievable, 2-7/8" x 7" X-Nipple, 2-7/8", 2.313" ID WLEG 7" Retainer Crossover, 3-1/2" x 2-3/8" GLM, 2-3/8" Merla 'TMPDX' S-Nipple, 2-3/8" Gravel Pack Packer, Baker, SC-1L Shear Out Safety Joint, 2-3/8", Baker Gravel Pack Screens, 2-3/8" Sump Packer, Baker DB Date Perforation Record Zone Top Bottom Amount Accum Item SPF 64-5 6522' 6556' 34 4 Proposed Perforations H-2 10,606' 10,628' 22' 14 Proposed Abandon H-3 10,644' 10,665' 21' 14 Proposed Abandon H-5 10,684' 10,714' 30' 14 Proposed Bandon PBTD = 10,960', TD = 11,005' MAX HOLE ANGLE = 4deg ~9300' DRAWN BY: tcb REVISED: 12/21/98 BOPE Variances Unocal Swanson River Unit August - September 2002 In order to operate Nabor's Well Service Rig 26 in Alaska, Unocal requires several variances to the requirements at 20 AAC 25.285. This approval is specific to the wells listed below. Due to the specific well type or work performed in advance, the chance to encounter hydrocarbons that can flow to surface is remote. Work on other well types using these specific waivers is not approved. SRU 32-33 WD WO SCU 13-34 WO SCU 33-33 WO SCU 24A-5 WO SCU 43B-8 WO SCU 21B-16 WO SRU 32A-15 WO - Replace Tubing/Packer - Replace Rod Pump - Repair Rod Pump - Install additional gas lift - Abandon Hemlock (?) Recomplete in Tyonek - Abandon Hemlock and recomplete in Tyonek - Replace corkscrewed tubing Unocal requested an exception to 20 AAC 25.066 to allow using a single LEL gas meter. Gas detection must comply with 25.066 for methane and H2S detectors (if necessary). This request is denied. Unocal proposed using high-pressure line(s) and hose with 1502 threaded connections which requires an exception to 20 AAC 25.285 (c) (9) and (e) (6). The waiver request is approved as provided by 20 AAC 25.285 (e) (6). With regard to the actual lines, hose (flexible, continuous) may be used. Steel pipe and traditional chicksan may not be employed. All of the valves Unocal plans to employ are manual. 20 AAC 25.285 (9) (C) requires that the outer choke valve must be a hydraulic valve. For the planned application with calculated pressures likely well below 2000 psi, this is acceptable and the waiver is approved as provided by 20 AAC 25.285 (h). The choke manifold does not have a bypass line per 20 AAC 25.285 (9) (D). The request for waiver should be approved as provided by 20 AAC 25.285 (h). Your approval of these recommendations is requested. I propose that a copy of this document with the appropriate well identified be attached to the workover Sundries as they are processed. A copy of this document is included as an attachment to the sundry approval for the respective well work. To; C. O. Taylor, Chair D. T. Seamount, Commissioner Fr: T.E. Maunder, PE Re: Variance Requests, Unocal Workover Rig Unocal has proposed bringing a "pulling Unit" to conduct workovers in Swanson River. This style rig is not ordinarily used in Alaska, but it is quite common in Canada and the lower 48. In order to operate the rig in Alaska, Unocal has requested several variances to the the requirements at 20 AAC 25.285. This document examines Unocal's variance requests and makes recommendations regarding them. Unocal has submitted a description and sketch of the proposed BOP equipment and arrangement. Unocal's request has been examined and evaluated according to the regulations by Tom Maunder and John Spauiding. John has physically inspected the equipment and Lou Grimaldi witnessed the initial BOP test on August 20, 2002. Unocal's stated intent is to perform work on wells that have passed AOGCC approved no-flow tests, a water disposal well and other wells that have existing perforations plugged prior to the dg moving over the well. This approval is specific to the wells listed below. Due to the specific well type or work performed in advance, the chance to encounter hydrocarbons that can flow to surface is remote. Work on other well types using these specific waivers is not approved. SRU 32-33 WD WO- SCU 13-34 WO - SCU 33-33 WO- SCU 24A-5 WO- SCU 43B-8 WO- SCU 21B-16 WO- SRU 32A-15 WO - Replace Tubing/Packer Replace Rod Pump Repair Rod Pump Install additional gas lift Abandon Hemlock (?) Recomplete in Tyonek Abandon Hemlock and recomplete in Tyonek Replace corkscrewed tubing Unocal requested an exception to 20 AAC 25.066 to allow using a single LEL gas meter. Gas detection must comply with 25.066 for methane and H2S detectors (if necessary). It is recommended that this request be denied. Unocal proposed using high-pressure line(s) and hose with 1502 threaded connections. 20 AAC 25.285 (c) (9) and (e) (6) are very specific with regard to connections being flanged or hubbed. However, (e) (6) allows the use of hammer unions if the Commission determines that those joints do not compromise the maintenance of well control. 25.285 (h) allows the Commission to approve a variance from the requirements if the variance provides at least an equally effective means of well control. Since the well work is unlikely to encounter flowing hydrocarbons, use of the threaded connections should not compromise maintenance of well control. The waiver request should be approved as provided by 20 AAC 25.285 (e) (6). With regard to the actual lines, hose (flexible, continuous) may be used. Steel pipe and traditional chicksan may not be employed. All of the valves Unocal plans to employ are manual. 20 AAC 25.285 (9) (C) requires that the outer choke valve must be a hydraulic valve. For the planned application with calculated pressures likely below 2000 psi, this is acceptable and the waiver should granted as provided by 20 AAC 25.285 (h). The choke manifold does not have a bypass line per 20 AAC 25.285 (9) (D). The purpose of the bypass line is to allow gas flows to be bypassed around the chokes to reduce pressures when gas surfaces during well control. In the specific wells where work is planned, the chance of encountering hydrocarbon is remote. The request for waiver should be approved as provided by 20 AAC 25.285 (h). Your approval of these recommendations is requested. I propose that a copy of this document with the appropriate well identified be attached to the workover Sundries as they are processed. T. E. Maunder, PE Senior Petroleum Engineer C.~:). Taylor, Chair D. T. Seamount, Commissioner Subject: Pulling Unit for Swanson Work Date: Fri, 16 Aug 2002 15:39:16 -0800 From: Tom Maunder <tom_maunder@adm in.state.ak, us> To: Tim Brandenburg <brandenburgt(~unocal.com>, Don Fowler <fowlerd@unocai.com> CC: AOGCC North Slope Office <aogcc_prudhoe._bay@admin.state.ak. us> Tim and Don, Sorry for the delay on this matter. I did receive your letter of August 8 which ! forwarded to some of the Inspectors to get their comments. As you and I have discussed, according to the text and diagram your proposal uses 1502 unions (threads) for all fluid line connections. Your proposal indicates that most "lines" will be 5000 psi hose although it is stated that the Kill Line will consist of 2", 3000 psi iron with threaded 1502 unions. You have also provided a description of the actual BOP system components which include an annular, a double ram, 4 manual valves and a choke manifold with 2 manual chokes and 5 valves. You also propose to have a single gas LEL monitor on the work platform. Gas detection requirements are found at 25.066. 3 methane and hydrogen sulfide detectors are required, in contrast to 25.285 (below), .066 has no provision to waive gas detector requirements. Any exception to the gas detection requirements would require a hearing with 30 days notice. The regulations for secondary well control for workover (20 AAC 25.285) are pretty specific with regard to flanged or hub connections.((9) and (e) (6)). However, (e) (6) allows the use of hammer unions if the Commission determines that those joints do not compromise the maintenance of well control. 25.285 (h) allows the Commission to approve a variance from the requirements if the variance provides at least an equally effective means of well control. Your choke/kill line valves and choke manifold appears to meet most of the regulations, with the exception of (C) and (D). Your outer choke valve is not remotely controlled and there does not appear to be a bypass line on your choke manifold. In consideration of the request, your proposal indicates that this unit will be used for workovers only (no casing entry) with the attempt to be isolated from any formation pressures. You have calculated a MASP according to the Commission's regulations of 1910 psi, although it is likely that there would not be any pressure due to the inability of the well to flow. Subject to an inspection by one of the Inspectors at the soonest practical opportunity, I can support your proposal modified as follows: 1. Once plugs are set, the wellbore must be pressure tested. Tests should be conducted similar to a MIT for injection wells. 2, All operations must be conducted with the wellbore full of fluid. Your stated intentions are to have the "working areas" of the wellbore isolated from the producing formations. Maintaining fluid at surface should not be a problem. 3. A single LEL meter is not acceptable. Gas detection must comply with 25.066 for methane and H2S (if necessary). 4. High pressure hose may be employed, however any connections must be kept to a minimum. Steel line with 1502 connections may not be employed. 5. No production perforations may be open to the "working area" of a wellbore. The disposal well may be worked over without isolating the perforations from the "working area". 6. With points I and 5 satisfied, the requirement for an outboard automatic choke valve and choke bypass line may be waived. As noted, we would appreciate notification as soon as practical so an Inspector may examine the rig and equipment. I understand that could be as early as Tuesday and likely would be at the first well to be worked on. Final acceptance of the assembled equipment will be based on the inspection conducted at that time and any recommendations from the Inspector. We also will witness the initial BOP test prior to your conducting work. Please assure that your representative contacts the Inspectors so one may be on site. Tom Maunder, PE 1 of 2 8/16/2002 3:39 PM AOGCC Tom Maunder <tom maunder~.admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 8/16/2002 3:39 PM Subject: Unocal I Nabors workover rig Date: Fri, 16 Aug 2002 15:14:03 -0800 From: trapper <trapper@matnet. com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, I can support the verbiage in the fax - as we discussed an inspector should review the rig prior to acceptance and attempting any well repairs. At that time if there are any questions, we should retain the rights to review and reconsider if necessary, ihs 1 of 1 8/16/2002 3:39 PM Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL RECE !,?: i' AUG 0 8 2002 Alaska 0il & Gas Cons. Cornmissm[, Anchorage Thursday, August 8, 2002 Mr. Tom Maunder AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Swanson River Workover BOPE Configuration Mr. Maunder: We are preparing to per[om well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling. Nabors is moving the unit here from their Nabors Production Services Unit in Alberta, Canada, inclusive of BOPE. We have reviewed the conventional BOPE rig up and equipment as used in Canada and have augmented it to satisfy our internal standards. We feel that the proposed system is superior to BOPE configurations that are presently in use in other oil and gas provinces in the United States and Canada for wells with equivalent pressure and flow regimes. Where practical we have taken steps to avoid exposure to the reservoir to allow for loading of the well bores with fluid. While this step is not being done for well control, it does provide the benefit of working in a closed wellbore with no open per[orations. The system as proposed would also be utilized on depleted wells with open per[orations and not capable of flowing any fluids or capable of maintaining a fluid column at surface. We consider the application of this and all BOP configurations to be a well specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on, the highest MASP and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. Tim Brande~bu~~~~~ Well Work Inventory 1 ea. Water Disposal well (Sterling)- plan to repair tubing leak. Non hydrOcarbon bearing zone. 2 ea. Gas Re-completions (Tyonek) Plan is to Abandon Hemlock (pre rig), de-comPlete and re-complete with pulling unit. No open perfs during rig work. 1 ea. Install Gas Lift (Hemlock Oil) Plan to install x-nipple below permanent packer so that reservoir will not be exposed during workover. 1 ea. Repair corkscrewed tubing in Hemlock Gas Lift Completion- plan to pick up hanger and remove pups. Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .lpsi/ft Gas Gradient) = 1,910psi MASP, Proposed Confi~luration BOP's Annular, 5K 7-1/16" Hydril or 11" Shaffer Double gate, 5K, 7-1/16" Hydril or 11" Shaffer Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator Wagner, 3000 psi, 60 gallon, 6 ea. 11 gallon, 100 gallon fluid reservoir, 2 ea. nitrogen back up bottles, 10 hp electric pump. Pits The pit consists of a 200 bbl tank partitioned into 100 bbl compartments. Pump The pump is an Oilwell 346 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron with threaded Fig 1502 Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16", 5K valves attached to either the mud cross or the tubing spool annulus valve. Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 5,000psi hoses with integral Fig 1502 Unions. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and five valves. There are two valves upstream of each choke. Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with threaded Fig 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the two 100 bbl compartments of the pits. It is constructed per the Canadian practice with an open bottom that utilizes the hydrostatic level in the tank for the water leg as is Nabors Rig 129 (Formerly H and R Rig 9 also from Canada). The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT sysyem as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. 1502 . . ----- 1502 THD - . - . '.' : . ~.~'~.. ~w~ .~. . . _ . ..,~ ~- ~t~,~~_~- ?. Authority: AS 31.05.030 20 AAC 25.275 RESERVOIR FLUID PROPERTIES Repealed or Renumbered Repealed. History: Elf. 4/2/86, Register 97; repealed 11/7/99, Register 152 Editor's Notes: Effective 11/7/99, Register 152, the substance of 20 AAC 25.275 was relocated to 20 AAC 25.270. 20 AAC 25.280 WORKOVER OPERATIONS. (a) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission in order to enter a well and conduct one or more of the following types of well workover operations: (1) the perforation or reperforation of casing; (2) stimulation; (3) the pulling of tubing; (4) alteration of the casing; (5) repairs to the well. (b) The Application for Sundry Approvals must set out (1) the current condition of the well; (2) a copy of the proposed program for well work; (3) unless already on file with the commission, a diagram and description of the well control equipment to be used, including if applicable a list of the blowout prevention equipment (BOPE) with specifications; (4) a description of any wellbore fluid to be used for primary well control; and (5) the current bottom-hole pressure, or, if data setting out the actual pressure are not available, an estimate of the current bottom-hole pressure. (c) The operator shall keep records and reports of well workover operations, including BOPE test results, in conformance with the requirements of 20 AAC 25.070 (~). (d) The operator shall file with the commission, within 30 days after completion of workover operations, on a Report of Sundry Well Operations (Form 10-404), a complete record of the work performed and the tests conducted, and a summary of daily well operations as described in 20 AAC 25.070 (3). Upon request, the operator shall file with the commission a copy of the daily record required by 20 AAC 25.070(1). 59 (e) Upon application, the commission will, in its discretion, waive the requirements of this section for wells in a pool for which pool rules have been prescribed under 20 AAC 25.520. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 20 AAC 25.285 SECONDARY WELL CONTROL FOR TUBING WORKOVER OPERATIONS: BLOWOUT PREVENTION EQUIPMENT REQUIREMENTS. (a) This section applies to workover operations performed with the tree removed. These operations are also subject to the requirements of 20 AAC 25.527. (b) The rated working pressure of the BOPE and other well control equipment must exceed the maximum potential surface pressure to which it may be subjected. If an approved Application for Sundry Approvals (Form 10-403) is required under 20 AAC 25.280, the commission will specify in that approved application the working pressure that the equipment must be rated to meet or exceed. However, the rated working pressure of the annular type preventer need not exceed 5,000 psi. (c) Well control equipment must include (1) at least one positive seal manual or hydraulic valve or BOPE blind ram and one set of BOPE pipe rams flanged to the wellhead; (2) in rotary drilling rig operations, (A) for an operation requiring a BOP stack less that API 5K, at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; and (B) for an operation requiring a BOP~stack equal to or greater than API 5K, at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe, tubing, or casing being used, except that pipe rams need not be sized to BI-lAs and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; (3) in coiled tubing unit operations, (A) for an operation requiring a BOP stack equal to or less than API 5K, 60 (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) a high pressure pack-off, stripper, or annular type preventer; (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (iv) at least one preventer equipped with pipe rams that fit the size of the tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation requiring a BOP stack greater than API 5K, (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) two high pressure pack-offs, strippers, or annular type preventers; (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (iv) at least two preventers equipped with pipe rams that fit the size of the tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; (4) if a tapered string is used, either an additional set of rams for each size of pipe being run or a variable ram, except if small diameter tubulars are used to perform a clean-out operation through a production packer or to clean out a liner where the casing has been top set; (5) locking devices on the ram-type preventers; (6) in rotary drilling rig operations, one complete set of operable remote BOPE controls on or near the driller's station, in addition to controls on the accumulator system; (7) in coiled tubing operations, one complete set of operable remote BOPE controls on or near the operator's station and, if these controls are not in close proximity to the drilling platform floor, a second annular type preventer closing control located on the drilling platform floor; (8) a hydraulic actuating system with (A) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPs, except blind rams, are closed and all power sources are shut off; and (B) an accumulator pump system consisting of two or more pumps with independent primary and secondary power sources and an accumulator 61 backup system having sufficient capacity to close all BOPs and to hold them closed; (9) a kill line and a choke line each connected to a flanged or hubbed outlet on a drilling spool or on the BOP body with two full-opening valves on each outlet, conforming to the following specifications: (A) the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig operations, if the required BOP is rated equal to or greater than AP1 5K, the nominal diameter of the choke outlets must be at least three inches; (B) each valve must be sized at least equal to the required size of the outlet to which it is attached; (C) the outer valve on the choke side must be a remotely controlled hydraulic valve; (D) the inner valve on both the .choke and kill sides may not normally be used for opening or closing on flowing fluid; and (10) a choke manifold equipped with (A) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's station if the operation requires a BOP stack equal to or greater than AP1 5K; (B) a line at least two inches in nominal diameter downstream of each choke; (C) immediately upstream of each choke, at least one full-opening valve for an operation requiring a BOP stack less than API 5K, or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; and (D) a bypass line, at least two inches in nominal diameter, with at least one full-opening valve for an operation requiting a BOP stack less than API 5K, or at least two full-opening valves for an operation requiting a BOP stack equal to or greater than API 5K. (d) The rated working pressure of valves, pipes, rotary hoses, and other fittings, including all sections of the choke manifold that are subject to full wellhead pressure, must exceed the maximum potential surface pressure to which they may be subjected and may not be less than the required working pressure specified for the BOPE in an approved Application for Sundry Approvals, if any, under 20 AAC 25.280, except that the rated working pressure of lines downstream of the choke need not exceed 50 percent of the required working pressure of the BOPE. (e) Kill and choke lines must (1) be constructed of rigid steel pipe, fire-resistant rotary hose, or other conduit that has been approved by the commission as capable of withstanding the temperature and pressure of an ignited uncontrolled release; (2) be as straight as practical; (3) if constructed of rigid steel pipe, use targeted tums where the bend radius is less than 20 times the inside diameter of the pipe; 62 (4) be secured to prevent excessive whip or vibration; (5) be sized to prevent excessive erosion or fluid friction; and (6) be assembled without hammer unions or internally clamped swivel joints, unless the commission determines that those joints do not compromise the maintenance of well control. (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if BOP sealing ram type equipment has been used, it must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstdng is pulled out of the well and the BHA clears the BOP; (4) test results must be recorded as part of the daily record required by 20 AAC 25.070 (1); (5) at least 24 hours notice of each function pressure test must be provided so that a representative of the commission can witness the test. (g) In a rotary drilling rig operation, the operator shall have on location a copy of the approved Application for Sundry Approvals, if that application is required under 20 AAC 25.280, and shall post on the drilling rig floor any geologic hazard information obtained while drilling the well and a copy of the operator's standing orders specifying well control procedures. In a coiled tubing operation, the operator shall post in the operator's cab a copy of the approved Application for Sundry Approvals, if that application is required under 20 AAC 25.280, any geologic hazard information obtained while drilling the well, and a copy of the operator's standing orders specifying well control procedures. If an additional or separate substructure is used in a coiled tubing operation, the operator shall post a second set of standing orders on the drilling platform floor. (h) Upon request of the operator, the commission will, in its discretion, approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. 63 History: Eft. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 20 AAC 25.286 WELL CONTROL REQUIREMENTS FOR WORKSTRING SERVICE OPERATIONS. (a) This section applies to through-robing operations that are not subject to the requirements of 20 AAC 25.036 or 20 AAC 25.285, and that are performed with coiled tubing, small diameter drill pipe, or small diameter tubing. These operations are also subject to the requirements of 20 AAC 25.527. (b) The operator shall use a full lubricator system or open hole deployment type system. (c) The rated working pressure of the blowout prevention equipment (BOPE) and other well control equipment must exceed the maximum potential surface pressure to which it may be subjected. If' an approved Application for Sundry Approvals (Form 10- 403) is required under 20 AAC 25.280, the commission will specify in that approved application the working pressure that the equipment must be rated to meet or exceed. However, the rated working pressure of the annular type preventer need not exceed 5,000 psi. (d) Well control equipment must include (1) at least one positive seal manual or hydraulic valve or blind ram flanged to the wellhead or tree; (2) in rotary drilling rig operations, (A) for an operation requiring a BOP stack equal to or less than APl 5K, at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; and (B) for an operation requiring a BOP stack greater than API 5K, at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe, tubing, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; (3) in coiled robing unit operations, 64 STATE OF ALASKA ALASKA OrL AND GAS CONSERVATIOi -4;OMMISSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: _.~/ Alter casing: X Repair well: Plugging: ~me extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: ~ther: 2. Name of Operator 5. Type of well: 6.-Datum.elevation/CF or KB) Union Oil Company of California Development: X KB: 168'/,' feet 3. Address Exploratory: 7. Unit or Prop/e~ty name P.O. Box 196247, Anchorage, Alaska 99519 Stratigraphic: Soldo~3,Creek Unit Service: / 4. Location of well at surface 8. Well,umber 657' FNL& 1985' FWL, Sec. 16, T7N, Rgw, SM , S~U 21B-16 At top of productive interval 9. At effective depth /~ 0. APl number 50-133-10132-02 At total depth 11. Field/Pool 441' FNL & 1906' FWL, Sec. 16, T7N, R9W, SM Swanson River Hemlock and Tyonek Gas 12. Present well condition summary / Total depth: measured 11005 feet Plugs (measuredy true vertical 11000 feet // / Effective depth: measured 10960 feet Junk (measFf¢;l)' Casing Length Size /,~ ?e~nted .---Y Measured depth True vertical depth Structural Cellar / ~7 Conductor 35' 22' ¢'/~on¢ction cement 55' 55' Surface 2013' 11-3/4" V ')// 1600 sx_ 2035' 2035' Production 11023' 7'* ~ st stage 600 sx 11045' 11045' ~ .,/2nd stage 1200 sx Liner 2301' ~"~ )// 275sx 11004' 11000' *Section cutf/9100'-9150'MD \ .~ / Perforation depth: measured Existing (~,0 0~1~28 1, 0644-10665, 10684-10714') Proposed (6520-6556') Tubing (size, grade, and measured depth)///3/1/2', J-55 to 8569', . 2-31~',_ ~0~o.107...4~' Packers and SSSV (type and measured depth)//' SO1-L gravel packer 10,341'; Baker DB sump packer @ 10740' 13. Attachements Description summ/~ of.proposal: X Detailed oparatio~s program; BOP sketch: / 14. Estimated date for commencing oparatioy 15. Status of well classification as: May, 2002 ./ 16. If proposal well verbally approved: ~ Oil: X Gas: X Suspended: current change to gas Name of ap~ver // /I Date approved Service: 17. I hereby c~rtify~that the fol;eg.oir~is t/p/~/and correct to the best of my knowledge. Signed: ~~A ~X/~-~ ~,(/~~~ Title: Drilling Manager Date: ~'~ ~,.~ ~¢,~ v " ' '"'/ - FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may wi~ess IApproval No. Plug integrity7/__~ BOP Test __ Location clearance__ MechanTteg. rity Test ' Subsequent form required 10- Cot~ftfi~s~otle~' Date Approved by order of the Commms~oner Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE SCU 21B :_ Casino Conductor Pipe - 22" ~ 36' Surface Casing - 11-3~'4', 47#,J55 @ 2035' Production Casing - 7', 29#& ~6#&23 .. @ 9100' ' Liner- 5" BO, 87(: Tubino Detail ~ (Depths ~¥LM-RKB) .1. 3-1/2", 9.3#, J55 Tubing 8569 . Z 3-1/2.- x 2-3/8" Crossover 8569 3 2-3/8",4.7#,N80 Tubing 8570 4_ 2-3/8' Merla q'IVlPDX' GLM 7", 29#&26#&238, N80&P110 5" 1 68, N80, 8704- 11,004' ID 10270 ~. 2-3/8" Otis 'S' Nipple 2.992" 6 Baker SCl-L Gravel Packer 1.995" Z. 2-3/8" Baker 'GP Safety Joint 10307 1.875" 8 2-3/8",4.68, N-80 Blank Pipe 10341 4.00" 2-3/8" 4.68, N-80 Bakerweld~ 0.012 Gravel Pack Screens 10364 10 2-3/8" O- Ring Seal Sub 10365- 11 2-3/8" 4.68, N-80 Bakerweld 0.012 Telltale Screens 10604 Baker 'DB Sump Packer 10729 1 .~15" _Perforation Detail (Depths WLM-RKB) H2 - 10,606' - 10,62~' 14 SPF H3 - 10,644' - 10,665' 14 SPF H5 - 10,684'- 10,714' 14 SPF 10730 10740 PBTD-10,772 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501'''''''~ Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager May 1,2002 Alaska Oil & Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501 Attention: Mr. Tom Maunder Subject: Soldotna Creek Unit Well 21 B-16 APl No. 50-133-10132-02 10-403 Perforate Tyonek Gas Dear Mr. Maunder: Unocal requests approval to recomplete Soldotna Creek Unit Well 21 B-16 into a small Tyonek gas accumulation (Tyonek 64-5s). Proposed work: 1. Set a retrievable plug in the 2-3/8" tubing above the existing Hemlock completion. 2. Run perforating guns and perforate through the production tubing and casing from 6520-6558' (above the current production packer). 3. Produce natural gas up the tubing string. If you have any questions, please contact Gary Orr at 263-7858. /Si~erely,/~,/0/7/// Dan Williamson Ddlling Manager TO' ADDRESS' ARCO ALASKA, INC, Cook Inlet/New Ventures Engineering LOG TRANSMITTAL FROM: DATE: WELL' Please find the following logs enclosed: Lo9 Blue *** Sepia *** Line Folded Rolled Mylar Tape . /. /. . . Receipt Acknowledgment- Date' Return Receipt to' ARCO Alaska, Inc. ATTN: Judy Boegler ATO-.l~q~ Post Office Box 100360 Anc.horage, AK 99510 ~ % · THO -...~ t502 THO 1502 THD WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well' OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] r~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-0255 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 133-10132-02 · 4. Location of well at surface 9. Unit or Lease Name 657' FNL, 1985' FWL, Sec.16, T7N, R9W, SM Soldotna Creek Unit At Top Producing Interval 10. Well Number 468' FNL, 1910' FWL, Sec.16, T7N, R9W, SM SCU 21B-16 At Total Depth 11. Field and Pool 441' FNL, 1906' FWL, Sec.16, T7N, R9W, SM Swanson River-Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 168' GL 148'I A-028993 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/06/85 12/04/85 12/24/85 *I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11005'MD, 11000'TVD 10960'MD, 10955'TVD YESJ~] NO[-] N/A feetMDI N/A 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, DNL/LDT/Cal/GR, SDT/GR, CET, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22,, .... 26, 55, .... 11-3/4" 47# J-55 22' 2035' 16" 1600 sx 7" 23,26,29# N-80 22' 11045'* 9-5/8" 1st 600 sx~ 2nd 1200 sx 5" 18# N-80 8704' 11004' 6" 275 sx · S .~cti on cut 19100 ' -9150 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10606'-10628'MD 10601'-10623'TVD 3-1/2"/2-3/8" 10743' 10341' & 10740' 10644'-10665'MD 10639'-10660'TVD 10684'-10714'MD 10679'-10709'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Above 6 - 1/2" JSPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 01/08/86J F1 owing Date of'Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 12/25/85 1~.75 TESTPERIOD I~ 135 1004 0 VariousI 7438 Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pres~.300 0 24-HOUR RATE ~ 968 7200 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No conventional cores or sidewall cores taken. '.::: ,i";; ,~'~: !--~ -.,r' ~ · tqO?~.: ~/oz:kove~: :~er£oz'mecl 5/12/87. Form 10-407 WC3/1 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Hemlock Fm. Hy Pt. GEOLOGIC MARKERS 31. LIST OF ATTACHMENTS None MEAS. DEPTH 10580 ' 10723 ' TRUE VERT. DEPTH 10575' 10718' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. No DST's were conducted 32. I hereby certify that the foregoing is true and correct to the best of my knowledge tT-'~¢'~L.t-/.~-C"~J Date Signed ~ (,~,/) (/'~( / _ Title Associ ate Engj neet Cc'- ,,'-c-, / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing toot. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA .... '- AL~,..,(A OIL AND GAS CONSERVATION CO,....IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other Stimulate [] Plugging ~ Perforate ~ Pull tubing W0RKOVER 2. Name'of Operator ARCO Alaska, Inc. 3. Add[ess - P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 657' FNL, 1985' FWL, Sec.16, T7N, At top of productive interval 468' FNL, 1910' FWL, Sec.16, T7N, At effective depth 449' FNL, 1906' FWL, Sec.16, T7N, At total depth 441' FNL, 1906' FWL, Sec.16, T7N, Rgw, SM R9W, SM R9W, SM R9W, SM 5. Datum elevation (DF or KB) RKB 168' Feet 6.~Un. it. qr Pro~pert. y name boloo~;na creeK Unit 7.Well number SCU 21 B-16 8.Approval number 7-170 9. APl number 50-- 133-10132-02 10. Pool Swanson Ri ver-Heml ock 11. Present well condition summary Total depth: measured true vertical 11005 ' MD 11000 'TVD feet feet Plugs (measure,d) Fill ~ 10772' Effective depth: measured 10960'MD true vertical 10956'TVD feet feet Junk (measured) None Casing Length Size Structural Cellar Conductor 35' 2'2" Surface 2013' 11 3/4" Production 11023' 7"* Liner 2301 ' 5" *Section cut f/9100 '-9150 'MD Perforation depth: measured Cemented Measured depth Constructi on Cement 1600 sx Class G 1st stage 600 sx, 2nd stage 1200 sx 275 sx Class G 55 'MD 2035 'MD 11045 ' MD 11004 'MD 10606'-10628', 10644'-10665', 10684'-10714' True Vertical depth 55'TVD 2035'TVD ll04$'TVD 11000'TVD true vertical 10601'-10623', 10639'-10660', 10679'-10709' Tubing (size, grade and measured depth) 3-1/2"/2-3/8", J-55/N-80, tubing w/tail @ 10743' Packers and SSSV (type and measured depth) SC1-L GP pkr @ 10341' and D Sump pkr @ 10740' 12. stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well oPeration Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover' Well Histor~) Daily Report of Well Operations L~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 ¢ (Dani) 5W02/35 Date Submit in Duplicate ARCO Oil and Gas Company "' Well History- Initial Report - Daily Instruction~: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Swanson River Auth. or W.O. no. AFE 498645 ICounty. parish or borough North Slope Borough Lease Designation A-028993 or Unit JTitle Re-completion IState Alaska IWell no. SCU 21B-16 Roll'n #5 API 50-133-10132-02 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover I ARCO W.I. IDate4/20/87 IH°ur 2230 Hrs, [Prior status if a W.O. Date and depth as of 8:00 a.m. 4/21/87 4/22/87 4/23187 4/24/87 4/25/87 thru 4/27/87 4/28/87 4/29/87 Complete record for each day reported 5" @ 11,004' 9.0 ppg brine Accept rig @ 2230 hfs, 4/20/87. ND tree· NU & tst BOPE. 5" @ 11,004' 9.0 ppg brine Att to tst BOPE. wait on & repl HCR vlv. Tst BOPE. 5" @ 11,004' 9.0 ppg NaC1 Tst BOPE. RU DA, cut tbg off @ 10,462' · POH, LD tbg. 5" @ 11,004' 10,462' Fsh, PU 3~' DP 9.2 ppg Brine POH, LD 266 its, 2-7/8" tbg & 57 its, 2-3/8" tbg. 3-1/2" DP. RIH w/OS & 2-3/8" grapple. RU to rn 2-7/8" & 5" @ 11·004' 10,772' PBTD, ND BOPE -9.0 ppg Brine RIH w/3½" DP, rotate onto fsh, rotate fsh free, rev circ, POH, LD fsh. Tag fill @ 10,680', circ & rotate to 10,772'. Circ & filter brine. Mill pkr. RIH w/Bkr Model "C" BP. 5" @ 11,004' 10·772' PBTD, POOH w/3-1/2" DP 8.9+ ppg NaC13 ND BOPE & tbg-head. Cut piece off 7" stub. NU ne~ head, packoff would not tst. Chg'o~t packoff. NU tbg head, tst packoff; OK. NU &~tst. BOPE; OK. RIH & screw into storm pkr, tst csg above 5" BP to 2100 psi; OK. LD storm pkr, RIH & rel 5" BP. Circ& POH. 5" @ 11·004' 10,772' PBTD, RD' DA 8.9+ ppg ~aCl~ Fin POH w/5" BP. RU DA, att to perf; CCL failed. Rn GR/CCL f/10,753'-10,700'. Perf 10,684'-10,714', 10,644'-10,665' & 10,606'-10,628' @ 4 SPF. RD DA. The above is correct Date 5/21/87 ]Title Drilling Supervisor -For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish Field Lease or Unit Swanson River Lease Designation A-028993 Date and depth Complete record for each day while drilling or workover in progress as of 8:0~ a.m. 4/30/87 Alaska North Slope Borough IState Alaska Well no. SCU 21B-16 5/01/87 5/02/87 thru 5/04187 5/05/87 5/06/87 5/07/87 5" @ 11,004' 10,772' PBTD, Setting pkr 8.9+ ppg NaCi~ RIH w/pkr & p~rf guns, RIH on 2-3/8" tbg. RU DA, rn GR correlation, POOH; tight spot in DP. Space out tbg, RIH w/GR; stuck @ 920', POOH. POOH w/DP to 920'. PU 2 jts, RIH, prep to displ tbg w/crude & set pkr. 5" @ 11,004' 10,772' PBTD, RIH w/perf assy 8.9+ ppg NaClo Displ tbg/DP To crude, att to fire guns. Flow well to tank setting f/15 min. Rev circ, kill well, POOH. Guns did not fire. Break dn perf assy & reassemble. RIH w/perf assy. 5" @ 11,004' 10,772' PBTD, Build brine 9.0 ppg NaC12 Brine RIH w/TCP assy, set pkr @ 10,524'. DiSPl DP/tbg to crude. Perf 10,606'-10,628', 10,6~4'-10,665' & 10,684'-10,714' @ 4 SPF, 90° phasing. Flow well to tank setting, allow to cln up. Rev circ, kill well. POOH, LD perf assy. Make cln out rn, circ & filter brine, spot hot diesel/solvent pill across perfs, wrk pipe & rev out pill. Circ & filter brine, POOH. PU 5" RAM & 212' 2-3/8" tailpipe, RIH to 10,772', circ & filter brine. Pull 7 stds DP, set pkr @ 10,152' MD. Open by-pass & pmp 5 bbls gel, 15 bbls 10.0 ppg gravel slurrry & 5 bbls gel. Displ w/NaC1 brine to pkr. Close by-pass & start sqz pre-pak. Pkr or wrk string failed. Shut dn & rev out sand. 5" @ 11,004' 10,772' PBTD, RIH w/3½" DP 9.0 ppg NaC12 Brine RIH, tag btm @ 10,772' MD, rev circ hole cln, POH. w/10 its 2-3/8" tailpipe & RIH. PU 5" RAM 5" @ 1-1,004' 10,772' PBTD, Rev. out work string. 9.0 ppg NaC12 Brine Washed out sand to 10,772', treat w/4000 gal HCL, prepack w/20/40 ISP. 5" @ 11,004' 10,772' PBTD, POOH w/pkr & tailpipe 9.0 ppg NaCi? Circ & filte~ brine. Wsh fill f/10,498' to PBTD, circ & filter. POH. The above is correct ~ ! For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 5/21/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Inslructiona: Prepare and submit the "Final Report" on the first-Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska IWell no. SCU 21B-16 District IC°unty or Parish Alaska I North Slope Borough Field ILease or Unit Swanson River I Lease Designation A-028993 Auth. or W.O. no. ITM AFE 498645 I Re-completion Roll'n #5 Operator ARCO Alaska, Inc. A.R.Co. W.I. Spudded or W.O. begun Date Workover 4/20/87 Date and depth Complete record for each day reported as of 8:00 a.m. 5/08/87 5/09/87 thru 5/11/87 5/12/87 thru 5/13/87 Old TD Released rig 1500 Hrs. Classifications (oil. gas, etc.) eli Producing method Flowing Potential test data API 50-133-10132-02 Iotal number of wells (active or inactive) on this, DSt center prior to plugging and I bandonment of this well our I Prlor status if a W.O. I 2230 Hrs. 5" @ 11,004' 10,772' PBTD, Space out DP 9.0 ppg NaCi~ POH. RU DA,ZRn 4" OD GR, POH. RIH w/5" sump pkr, set @ 10,731' WLM. PU gravel pak assy, RIH on 2-3/8" tbg & 3½" DP, tag sump-pkr @ 10,735' DPM. Space ou[ DP. 5" @ 11,004' 10,772' PBTD, Tally tbg 9.0 ppg NaCl^ MU circ head~ rev circ hole vol. Set gravel pak pkr &tst to 1500 psi. Displ 15 bbls 20/40 slurry & screen out @ 2700 psi in upper & lower circ position. Rev wrk string. Tst gravel pak to 2700 psi, all to bleed to 0 psi. PU above rev position & observe well; no fluid loss. POOH w/wrk string & LD gravel pak tls. Rack & tally 3-1/2" 8RD AB Mod tbg. 5" @ 11,004' 10,772' PBTD, RR 9.0 ppg NaCi? Rn 270 its 3=1/2'' x 57 its 2-3/8" compl& lnd. SC1-L GP Pkr @ 10,341', "D" Sump pkr @ 10,740' & end of tbS @ 10,743'. LD sub-base to ND BOPE. NU &tst tree to 5000 psi. RR @ 1500 hfs, 5/12/87. INew TD Date I PB Depth Kind of rig 5/12/87 IType completion (single, dual, etc.) Single Official reservoir name(s) Swanson River 10,772' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day . Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct 5/21/87 Drillin$ SupervisOr see Procedures Manual, Section 10, Drilling, Pages 86 and 87. "~-'"-. STATE OF ALASKA - ALAS .... OIL AND GAS CONSERVATION COMk ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~. Plugging [] Stimulate .~, Pull tubing~' -~"Amend order .'~ Perforate~Other 2. Name of Operator ARCO A'laska~ Inc Anchorage, AK 99510-0360 3. Address P. O. Box 100360 5. Datum elevation (DF or KB) Ri(IS 1~;~' 6. Unit or Property name So'ldotna Creek Unit 7. Well number SCU 21B-1 6 8. Permit number 85-0255 9. APl number 50-- 133-1 0132-02 10. Pool Swanson River - Hemlock 4. Location of well at surface 657' FNL, 1985' FWL, Sec.16, T7N, R9W, SM At top of productive interval 468' FNL, 1910' FWL, $ec.16, TTN, Rgw, SM At effective depth 449' FNL, 1906' FWL, Sec.16, T7N, RgW, SH At total depth 441' FNL, 1906' FWL, Sec.16, T7N~ R9W~ SM feet 11. Present well condition summary Total depth: measured 1 I, 005 ' MD feet true vertical 11,000'TVD feet Effective depth: measured 1 0,960 ' M D feet true vertical feet 1 0,956' T VD Casing Length Size Structural Gel lar Conductor 35 ' 22" Surface 2013 ' 11 -3/4" Production 11 ,023' 7"* Liner 2301 ' 5" *Section cut f/9 Perforation depth: measured 10,606'-10,628', 10,644'-10,665,, 10,684 true vertical Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth Construction Cement 1600 sx Class G 1st stage 600 sx, 2nd stage 1200sx 275 sx Class G 100'-9150'MD '-10,714' 55 'MD 55 'TVD 2035'MD 2035'TVD 11 ,045'MD 11 ,045'TVD 10,601'-10,623' 10 639'-10 660' 10 679'-10 709' Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80~ EUE 8rd to 8666' & 2-3/8"~ 4.7#, N-80, EUE 8rd to 10,547' Packers and SSSV (type and measured depth) Baker 5" FH pkr (~ lO;477' 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch~ 13. Estimated date for commencing operation March 23, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. (~?'~/~/?/~.,; .~._~~,J~ ., Title Associate Engineer Date ,=.~-]'7--~7 / - - Commission Use Only (JG) 5A2/25 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI --~/? (~' APproved by 'TVD ........... C6mmissioner Dy oroer OT ' ~--~ the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate SCU 21B-16 WORKOVER GENERAL DISCUSSION SCU 21B-16 was completed 12/24/85 with a 2-3/8" x 2-7/8" tapered tubing string and a single 5" FH retrievable packer. Initial production was reported to be 860 BOPD/12 BWPD with a 11,200 GOR. In November, 1986, production had declined to 162 BOPD/3 BWPD with a 39,000 GOR. Sand and gravel were produced and fill was confirmed at 11,655'MD on 12/05/86. By January, 1987, the following wellbore problems had been diagnosed' 1. The secondary seals on the 7" packoff were leaking. 2. The tubing hanger leaked. 3. The top and bottom master valves leaked. 4. The packer leaked. 5. Some lockdown screws on the tubing spool leaked. 6. There was a hole in the tubing @ 10,454'. For safety reasons, SCU 21B-16 was killed on 02/12/87. This was accomplished by circulating 9.3 NaC1 brine through an open gas lift mandrel @ 8590' and bullheading a calcium carbonate pill into the perforations. The primary objectives of this workover are to recover the existing completion string, clean out the sand fill, gravel pack the production intervals and recomplete. See attached Workover Summary for additional details. ANTICIPATED BOTTOMHOLE PRESSURE: 4600 psi WORKOVER FLUID: 9.0 ppg NaC1 brine GRU1/57 SCU 21B-16 Workover Summary 1. MIRU workover rig. 2. ND tree. NU and test BOPE. 3. Spear tubing. Release packer. 4. Circulate out gas and oil and condition brine to 9.0 ppg. 5. LD 2-7/8" completion string. 6. Clean out 5" liner to 10768' MD. 7. Set retrievable BP. 8. Remove tubing head and install new secondary 7" seal unit. 9. Retrieve BP. 10. Perforate underbalanced w/6 SPF: 10,606'-10,628' 10,644'-10,665' 10,684'-10,714' 11. Gravel pack and recomplete with --3½" and 2-3/8" tubing. $R/29 ih -1- WELL PROFILE I7 8 J ~ J I0 16 17 NOT TO SCALE C~PaN¥ ARCO ALASKA, INC · ,v-~'..~.218-16 FIELD SOLDOTNA CREEK STAT~ ALASKA oA~ 12-85 COHPLETION DETAIL OESCRIPT!ON HIN lO HAX O0 LENGTH OEPTH INCHES INCHES FEET FEET I:UBII~ HAI~ER ' .55 2G.5~ ~U81~, 2-718' 6.5* ~ E~ ~ ~1.~ PUPS, 2-7/8" 6.5· N~O E~ 8rd 3.20 52.91 jBl, 2-7/8' 6.5· N~ E~ ~; 1~,15 I eL~, 2-7/8' CA~O ~ , .. 13.02 1~.26 I ]~BIH. 2-7/8" 6.~* NBO E~ ~d 1~.79 ,. ' eL~, 2-7/8' CA~O ~fl 12.~ 2701.~ i, (~81gS, 2-7/8' 6.5* HBO E~ ~d [TUBINg, 2-7/~' 6.5* NBO EUE ere ~5.72 , 6L~. 2-7/8' CA~CO ~ 12.63 41~.7e TUBING, 2-7/8' 6.5* NBO EUE ere eL~, 2-7/e' CA~O ~J : 12.~ ~.~ ~TUBme,. 2-7/8' 6.5· ~ EUE 8e~' J 314.72 J~ ' 6L~. 2-7/8' CA,C0 ~ 12.67 :rUBle, 2-7/8' 6.5* gBO EUE ~d 314.72 TUBING, 2-7/8' 6.5* ggO EUE ged I 1258.35 I~, 2-7/6' 6.5' g80 EUE 6rd j , I 1913.39 TUBING. 2-7/~' ~.S' H~O EUE 8rd ~TUBIN6, 2-7/6' 6.5' NBO EUE 8rd J j 63.53 ~ I i 12 !X-OVER, 2-7/8' x 2-3/8' EUE I :TUBING, 2-3/B 4.7' N-ilO EUE (tf, e i 13 j TUBING. 2-318 wi R A COLLARj · SLEEVE, 2-3/8' OTIS 'XA'J iTUBINe, 2-3/8 4.7' N-80 EUE 8rdJ 15 J PKR. BAKER S' TH' ~ ;TUBING. 2-3/B 4.7e N-BO EUE ere J 1.07 8666.44 ,1744.35 J 2.88 10443.27 NIPPLE, OTIS "X.' TUBING, 2-;5/8 4.7· N-80 EUE 8rd 17 i6R0t~ 6UN RELEASE SUB ~H ROT~ r:CN RELEASE/ 40K- STI~EiGHT PULL) J' 1.17 END OF TAIL 10477.46; 10514.~0 10547.17' ~ i10546.17! I' Current Completion DIAGRAM 2 WELL PROFILE CC~NY ARCO ALASKA, INC wt'U. 21B-16 Fla. I) $OLDOTNA CREEK .i I ALASKA 3-86 COHPLETION DETAIL 3½" 9.2#/Ft 3-55 ABM - 8704' m.. 7' ¢~ 9100' 2-$/8' 4.7* N-80 EUE 8r'd T'BG L0CATOR SEAL A$$El'lSLY (10'0F STI~0KE) -GRAVEL PACKER · 10330' PE~C~gATED NIPPLE i l -~0606' - !0628' ~0644' ~-~0665' ~ - !0684' ~ -10714' 3AFTEr! JOINT 1 240'- 2-~/8" ~LaNK 120' - 2-3/8" 46' N-BO NU IOrcl 012 GAOE wEJ. DED GP SCREEN I , I '0-~ING' SUB · ~0713' & :0' 2-3/8'T~LLTALE $C~EN · -~0725' 5' · ilO04' Proposed Completion ANNULAR PREVENTER ? PIPE RAILS § BLIND RAMS 3 2 1. 11 - 3/4" SURFACE CASING 2. 7" CASING HEAD 12" - 3000 PSI FLANGE ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. A,..~SURE THAT ACCUMULATOR PRE,55URE I,.5 5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS ,SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IAi)C REPORT. THE ACCEPTABLE LOWER LIMIT IS 4,5 ,SECONDS CLOSING TIME AND 1200 PS1 REMAINING PRESSURE. o , . . 10, ' 3. 12"- 3000 PSI X 6"- S000 PSI 11. TUB lNG HEAD 12. 4. 6"- S000 PSt X 11"- [5000 PSI 13. CROSS-OVER SPOOL, 5. 11"- 5000 PS1 BLIND RAMS 14. 6, 11"- 5000 PSI PIPE RAMS 7. 11"- 5000 PSI ANNULAR BOP STACK TEST :' i · , ,, FILL BOP STACK AND MANIFOLD WITH BR. INE. '~; .'!. ~ ~' !' CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY .RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN ,SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI, TEST KELLY COCKS AND IN,SIDE BOP TO 5000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DM MARCH 9, 1987 ~--- STATE OF ALASKA ~-- . ~_ ; AL. AA OIL AND GAS CONSERVATION C(. /IlSSION REPORT' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing [] Other EX 2. Name of Operator Chevron U.S.A. [nc. 3. AddresS P.O. Box 107839, .Anchorage, AK 99510 4. Location of well at surface 657' S & 1985' E of NW Cor. Sec. 16, 7N, 9W, SB&M At top of productive interval 468' S & 1910' E of NW Cor. Sec. 16, 7N, 9W, SB&M At effective depth 442' S & 1907' E of NW Cor. Sec. 16, 7N, 9W, SB&M At total depth 441' S & 1906' E of NW Cor. Sec. 16, 7N, 9W, SB&M 5. Datum elevation (DF or KB) K.B.=168 6. Unit or Property name Soldotna Creek Unit 7. Well number SCU 21B-16 8. Approval number 9. APl number 50-- 133-10132-02 10. Pool Hemlock Feet 11. Present well condition summary Total depth: measured 11,005 feet true vertical 11,000 feet Plugs (measured) Effective depth: measured 10,960 feet true vertical 10,955 feet Casing Length Size Structural Conductor 22" Surface 2013' 11 3/4" Intermediate 11,023' 7" Production Liner 2300' 5" Perforation depth: measured 10,606,_10,628' Junk (measured) Cemented Measured depth True Vertical depth 35' 1600 Sks 2035' 1800 Sks 11,045' 11,004'-8704' 11,004' 10,644'-10,665' 10,684'-10,714' true vertical 10,601'-10,623' 10,639'-10,660' 10,679'-10,709' Tubing (size, grade and measured depth) 2 7/8" 6.5# ¢.. 2 3/8" 4.7# N-80 ¢. 10,580' Packers and SSSV (type and measured depth) Baker: FH ~ 10,477' 35' 2035' 11,045' 10,999' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Title Acting Area Operations SuperintendentDate Submit in Duplicate D, ,.Y PROGRESS OF DRILLING WELLS o-562 BIT NO. F ROM FT. TO FT. / / SIZE MAKE-TYPE FEET HOURS JETS - A?.'- / / SIZE MAKE-TYPE FEET HOURS JETS FT. IN HRS. _ WT. ON BIT CONDITION CONDITION 1000# RPM SPEED DRILLING SETUP ? SIZE /DEPTH PUMP OUTPUT GPM ANNULAR VEL. F;UMP PRESS. FT./MIN. (D.P.) NOZZLE VEL. PSI@ SPM FT./SEC. DRLG. FLUID PCF .--MUD CO. - TYPE WEIGHT . #/100 SQ. FT. CC CC /32 Y I ELD PT. WATER LOSS HT-HP WATER' LOSS F I LTE R CAKE ..... . ~" PPM % PPM CHLORID'I~.' -' ' OIL CA pH ALK .G.A.LS (% MIN.) SURVEYS FUNNEL VISC. SEC. CPS PLASTIC VlSC. % SOLIDS SAND OTHER REMARKS -. -o CUMULATIVE CUMULATIVE '~' DA'LY COST // ~/7~ ?~Z''~_ Pro-562 (CD-4-78} Printed in U.S-A. PROGRESS OF DRILUNG WELLS · FIM:IM ......................... FT.TO It?. FT. Hid ........ HflS ......... 1QI)GI~ ' ' RPM m. oii"ii¥"- ."tO ' I~IL klflO SETUP__ PUMP OUTPUT __ GJ~4 ANWJL~ VT L. . .... I~,~lllilN. NOZZLE VEL. DIIU. O. FLUID ........ · ICI: ........ MC:. ~ GilD. -- .... ~q~lt ................... /N~j'~j~jj ...... f U~I~.L VlI~ Y~LCl, Ii'T, WATER tM HI.1 lldl)., #I-II'IILItS.. WAl't R L,01~ · ILTiR C:AIKS OAJI.Y PIIO6RE~ OF I)RiLLIll6 WELL~ Pm-~ Flti3M Itl', ~ II1'. Ff. IN Hfll ......... IOOe, ll .... WAT~JI LOCI HI-TEM/'.. Ht-~l~ Y/A?EJ~ tOM F~LTEJI C~LICe eoctol BA, LT OIL ....... ~ .......... PT. ~Lr ~ PH - ' -DALLY PR;O~~ OF §RtLUNG WEI. L~ Pr,,~j4i2 J~'T MZ~I~ IoOOm .................. Se.~o FORMATION PUMP pR~_~_. P~ WEK~T FUNNEL DAILY PROGRESS OF DRILLING WELLS Pro-SE! BIT NO. JE I' FT J~N, NOZZLe. v~t., Fr Jsc. c, W~G~T F I~tNE~ Vl..,q~ I~LAST~ tN ...................... ~TIVE DALLY DAILY PRO6U OF mum WEU~ P~i~mz iJlrl l&Mt, l ~ ~¥t~' mT m~u" I~.IId~CR~IRJT ........... OPM ANMU~APlYTL, .. . F'T~MN. ~ZLEV~-L,. ......... ~ JG' " ~ V~4. FTJiN. NOlt~t VEL. IrrJ'I~. WATU 011. ~' DALLY PROGRESS OF DRILLING W~-LS Pm,-562 FRC~ .......................... F'lr. I0 F'I'. F'T. IN ........... HPi:8. _ ...................... 1000~ _ WT. chq( BI'I' ,B~"E l I)P. ILL |NO S~TUP F'l'./141N. NOZ'ZL E VEL, DALLY PROGRESS OF DRILLING ~' .... TS Pro-562 I)RJLLIN6 f.,~RYS .......... CUI& RO'FATING liT:IS.. ......... WELL NIb.- ~'c ~ ~"~/._ ..~...~.._ Z~..~.. ............... FIELD ........ ~m~ ................................ mn NO ......... Ma, j~£ A~ IYH[ .............. PIT Ii0, slzI' I1~ I'T, 'fO .................. FT. _ ............... FT. DRILLING SETUP AT VEL. / ~ ........................ SEC. ......... tI~EJOH~ ~ l.J, Jq~k ~ R~"~lc vmc. WA'i'T R LOSS HI, 1 HAth. Ht--H~E,q~.,, W~.TE~ LOI~ Ir IL1 ER CAKF lot. IO~ CUMULI."I IV! P,AILY CG&'T RIG F'HOI~ HO. .................................................. ';;~"i~:,.-,, .............. ii',~ ................ i~.Aic'i, 'aim TY~'a FTM#. NOZZt.E V~_ FI~M ................ FI'. 'rD ............. F'I'. IN .......... ~ 1~ ~ ~n. ON mT .......... I~1i~' ..... NOZZLE V F.J.. IrT j~.C~. DAILY ~ OF MIILLING WELI~ ~ ~ pT, NA 1'141 IIAILy PIKIEIESS OF DRKLII6 WELLS PII-N2 FttOM ....... FI'.TO . ............ I~. I=1. ......... ~T~Ei 'liT. GIN BIT I~:! D &Id(I) ~d,T DN. I~ MAKE AMO T YI~ ~)""I : IMILY PROG~SS OF DKILLIII6 W~LI.,S i,l,...rd~ SLIf~/fy~ · · . ~f':~... ~./. ~ ......... "'/~,~ ;.. ................................... ............................ .~. .~'~" ?3... ~"..~ ..... ..~/.c ~.iLY I'ROGRESS OF DRILLING W'F. li~.. fe-542 y'~ _ .~'rc, z,A~ ........ saz.~ eu. jc~' ANt) 'f YI~I~ ~¥ slZral~ .... klLllO C~, 'TyII~ W~IC~HT FLJNfl~L ~ /1. Atlt~ VI:BiO,. YIIL C, II'T. We, TEA LCI~ HL?EMI'.. I'fl~lK1.iSn 1WA'! E l% LC,4:S F IZ. TI:R C. AX.[ SOLIDS ..... ff~. .... · ....... :.!~,~ _,~. .- ~ ...... ~/...~ ...... · U~¥8 ...................................................................................... I,y)Mz (cs)-?-?4~ DALLY PIIOGRE$S OF ORILLIIG WELL~ Pm-~ I~pULY III10~~ OF ORILUJI~ WEqq~_ ~ OF-TAll` ~UMkh.~TIYE I~11111 IX/TM ......... ~ AIIllUL~ VEL. FT Jill. tKXa~Li V[L. F'T./~C. 14I,'TIFMP. I'(:I-PIIG~I~ WATER LOliB F'III,'YI'A CAJ.~. lal~iiCll ....... (/~_ ~ ......... L.~ _.. ~- .... ~.. .... ~ ....... /~..: ~ . *t/~ *~ ...... f't. . ......... F'~, IN ~-Mla, .............. ~ ~ OUT]KII' ............... ~ ANNL~d:~i VEL. D~G, FLUID FlrMN. NO2ZLE VEL. Ir'T.FS, EC. YIILD PT. WAYI I1 LO~ I, II-TIM., Hi-Plli~ 8S,,. WATEFI LO,B8 IOLID8 D~TAI, L D~ ~Y ~ OF DILLI6 WELLS Fa Ii~lI ...... FT, TO ............. FT ...............F~. I:N ........ AT FORMA'~ IOI ~/ ~ III GPM ~ VtL. F'l',jbllflJ. IK)~L E VEL. F'l'.l~'~ F~fii~ Jn U.,1T.~, HALLIBURTON DIVISION LABORATORY SANTA FE SPRINGS. CALIFORNIA -- ANCHORAGE, ALASKA - LOS ANGELES DIVI.~ION MAINTAINED ElY HALLIBURTON COMPANY LABORATORY REPORT Nc ALC-307-85 Te Max Fritzel Dote n .... +~" ~' P 1985 This report is the property of Halliburton Services and neither it nor any port t~ereof nor o copy thereof is to De publisheo or disclosed without first securing the express written approval of laboratory management; it rnoy however, be used in the course of regular business operation by any person or concern and em- ployees thereof receiving such report from Halliburton Service~_. We give belay,' results of our examination of Kaiser Class "G", .6% FDP-C344, .3% HR-5 Submitted by Mr. Vince Anqel Chevron U.S.A. Marked Swanson River 21B-6_~ 11,000' Liner Schedule 1RO° RR~m PURPOSE Sample was submitted fOr Thickening Time Test Fluid Loss and Compressive Strength Test Slurry Compostion: Slurry Weight: Slurry Yield: Water Required: Test Conditions: Thickening Time: Compressive Strength: Fluid Loss: DATA Class"G", .6% FDP-C344, .~% HR-5 15.6 lbs. per gal. 1.18 cu. ft. per sack 5.2 gals. per sack 140° F and 5600 psi reached in 24 min. 3:38 hr:min 12 Hr. 16 Hr. 680psi 1760psi 43 cc/ 30 min. 18 Hr. 24 Hr. 1950psi 2100psi hoboratory Analyst R. C. Sharp CC: 1(, art h S2 ope Kenai Fi 2=_ NOTICE: Respectfully submitted, HALLIBURTON SERVICES This report is limited to the described ~ample tested. An), user of this report ogre~ that Halliburton shall not be liable for any los, or damage, whaler due to oct of omirsior~ mulling from such report or its use. FlqOI4 ............... FT. 1'0 ............ Ir'T, 1821~ ..... D~P'TH '"~ ........................ . Y~LD ~. MAKt ~ '~YI~ J~'T G~'G8 F~C~ ..................... Fl'. TO .... FT ............ F'(, m H~. ! GCIO~ ...... ~ - W~. i~"i~'ii -' t,~'ii .......... F'T JMiN. HOZZLE q~L. l'~nWJ bt YliLD IPT. ' ' WA'~r~ ~t' L'~'- %l.p~ ",v .................................................................. bX~1 PIg)GRESS OF DglLLIN6 wE~r~2 14AJ:E .I'Y'P'E FEE1 cc CliLC~K~ ..../.:~,..~ .......... ,,:,.. ~ .,~ at ~NI-IG~f r U#l~ L ¥1~r~.. - ~,L'Ji,~'Tm v~~. ~- ....... ~. ~. .... u~_ __RJ_~ .... ~_. l,r%.llp WAIE R LOe~ l It.lEK G;tf~! I~[~L I1~ S~ANI) I)ATI;I' PRO6R~ OF DIRTLR~ WT, LI.,T P'IW-~ CUMI,~.*.'I' TV F PROGRESS OF DRILLING WTLI. S ~ ATIVE DALLY COST DALLY PROGRE55 UF Di4,1LUNti 111:LL~ I'TB-IIeZ / I .... ~..-~' ,=, ...to ,l'~~. ...... ""' ~,l.,q~ ¥t., Y$ .......... tlOZZL [ ¥I.L. iX;AIL .............................................. CtlMUL A1 lIDO CUMUL ~'T DAk. Y ~ DALLY PROGRESS OF DRILLING WELLS Prl,.~2 il .............................................................elzr. MAKI-1'¢I~ FEET ............ ~- ~ ~'~ ....... /~$Y$ ,)...,,-,,',:o~ 37 $$ 0 $IJMVF. Y~ DAILY I)RO61SS OF DI~LLJN6 ~LLS Pm-BI2 t,~P~. ~C) ...... ~4M:0.4 44.. ....S..O[t f~$ .... ....................... B '-.1~.., PIK)GISS OF OKILUN6 WELLS D,F"Y PROGRES~ OF DRRUNG WELLS ~,o ~? ~'41't~.O0 ........................................................................................... $3, oq q Df '? PI~GliHI OF DRILLING WF. LI-~ r .662 ..... I ..q. ..... ~~ ri.. ......... .ti... b YtLLD I"1. qll~,l L Pi ~.~_-..~ ,__qo_~.,.o.o. _,~__~t,, .... J~ f~ .~p~,~<.~ ~aa~. .j4 _.F..._J 7RIPz~A . p.u.~p ...(.._&. ~..4e.. .~..t$.. tea ~ Al II/I DIM], Y OOl'l DJ'"Y PROGRES~ OF DRILLING WELLS r -S62 ['J~ULLItK; DA'i"~ .~,~' CUIILRO'TA,TI~G HRI~.. ..... .~J2 C L~ p~f 14 MUI:) CO. .NEC. lAP .~..~ - I K o~ooo .... b4 .~? - J.47~.~ ..... .. .Ro.T. ~ 7 ; v ~ ) ~o~... cu,w~,.^'r,vE ~$~..q..~ .~ .... PUMP OUTEqJ*~ .,,J~ ..... r. aq4 ANE~Jt, AR YEt... ./~,~" ...... fl./MN4. ~.P.! l~r,~zt, r V~. ~ ............. rT.JIEC. frl,'~El~ &Ak U,,,~.~u. D.4 ' PliOGIIESS OF {}I~LLING WI~I~ F )t~ ~'~c~w~_..,).."..._*'~. ~JeO ..rom~,.~_c~. ¥....-.~.~,:..~..4~.,,u~,mr~. .2, fO..~ ...... me, ...... BiZL I.UI,4~ OUl l, tJl ..~, ...~. ~11.... GImM &Nldtlt/d~ VF.L.. ..... d~..L J ..... I.'l ./Mild. {iXP.) NCNT'ZL E VEL.. .............. I~',~.L mum. .... DALLY PROGIliSS Of ORRLING WELi.~ I~ WtL~. ,O.. se~._ ~,J .4'/& ....... ~ AT Oiler ¥ COI'I DI ' PflOGREIS OF DRILLING WELLS iXIILLING L'u~YS .'.,I J. CUU. IIc~'rATIMO I~¢,I. _. Iii, oM L"IHIL L II~ M.1UP I~i i Dt P'f ii ............... pLJIbIp ¢~/TIN, J'I CPM A.qNULjId~, Vt fr.. t"f./hU~. ~J ~Lf YIL. .... Per .................. s~c. CUIUL AT DAILY DAII. Y PROGREIL~ OF DRILl. lNG WF.~ P'~..562 DJ~JLLII~ f~YI ..~J ..C~M, !10~11~ HFI~, ..... DJ'lit I IN~,i bic'l tJ'.~. l& x ~s/,,".,o.C,..- .:IA~,~ .. ~ x D,C,.. C ?~..~...~. ........... . , ~~.~ '~ ' ^ ~ . .q. . i c~. ' · FOFtMA1 ICH~I ...................... ~ Ju'RiS~.. .......,/.i~d~. 0 lj~,$' I N P'! II I'u~P CXJlI*Lrl.. &/~l~ GF~I ANINrU/)J4 VI I. Id~"" Fl JMIN. (D,f',J NOZZI. E VEL... CHI C)FII L~ OIL C;,A, ibl su,wYs...~tl~jot, ,/- ,t 8 a,~.,,,/,~4 p,e,u4,,i Wt IOH I ~ I-/NIl~ L VI6C:. I"L)',,~I lC vier.. · cc ..~: K/~_ .. lt...~ ....... ~. s ..... L,,._ ........................ (;AL.* ~ M~j O~ER REJa~ $.,4,bb.z,.¥lOb 0o~,',/ 3L~ A.¢.z:. .s/a 2' . ]4 ~., ~/-m,.~ .. i o..~ ........ ,0. ~. .... b ~.-t:-.,-.z ~., .... .0,, o..,0 ? .... ~b Y.A.? 4 -~ ~/.,Lk,, .~.~.. ........... .~..k~.,..4./.~.b-..: ................................................... p / e~ ~. . ..q..~ ............ 3 '!. u ,* ~, r. _ ' ......... 7~Jl_ .... ..... t~, ) ~J ......... C.. ~oT Df '~. PR061~$S 0f DRILUN6 WELLS F 562 ,,,,,. ,,., ~,,._. ,,.,.o ...... ..t, .... ~.'." ... %~~.,~o_%,,f~. · o__ ,, .. ~,~,0~,~._ &ri'leo .................... ,F,::ml al lO ") i.'t "to ....q'J,,l~ ~,"t. ~" J- Fr. . iN ./9 KFI~.._&:J.p.. to.od _~,i~ Q.&i~...-.,,L~p_ niN, i .O..~,U',0T .Su& ', ."/..A...~#/~'' D,e,, - ~A.W,$ - A. ,, '/.J/~ ~.,/~,..C ....................................................... PUk~OU'Tt, U'r. ldl&., aa',M AMNUi. A,RV~".. tW,,~' ......... F-,r.amN.. ~u,rJ NOZ2tLVt'L._ .................. F'T..mC;. " 'f'YF'lt "' ~Jmn ..... '~i..~iiM. L ~ .... /'¢);,~'m ~m,~. ' ' ~ ,h~om.,'T. 9,~ cc: ...................... cc .4,. _~..m....._1 "vtt g~.*' ' '~/~'1 f~ R LC'~ H'~l; WAlE R LCXB~ I Il, 1 ~' Iqr OAJf, E ._.%in.0.. ,,,,.. _o__,, ...ac,_,,,, /o :~_~..~ ... ~/...q. .... ~c .... xo_ .... L~ILC,~Ot OiL ~ I~i ALK GALS (t, idlN,3 0'1HI R III~MAPJCS ,L,~v~v~ .. ,~ O. ctct ~, ....... ~..q~...~.. ,1'.#, H. · t ~ .......................................... . ~.~...~- .C. g,~ .~..~ .......................................................................... -t DETAIl. O'Kn, y PIIOG~ OF ORILUNG WELLS UtPTli. DALLY PRO$~ OF Plllttll~ WELLS , v~l~ L'.n. W~11, It I (Jilt ...... i,n,41P WA'il Iq LO~I; F ILTF# CA/CE IOt~ ~ ..~o.o ~ __- ..... ~o.~...'~.c:) ....sJ~ _..q..//~ ...................... : ............. CHL cn,tll)~ ~ CA pJ~ ALK 6ALS {IG MINJ 0"114S I~ IltiMAItI~ ,,~dJ'R¥1 Y'TP ........................................................................ ri~ ~ ~r~...~ .J 0 $ t~.~.~.) DALLY PllO6~ OF DRILLING WELI~ Ptl..BI2 DI.L L Ilil rJ*,YI ..J ~. _ CUlK. FK~AT"m |'m~.. J/z P p..~. ....................... DA'~y P~OGRESS OF DRILLING WELLS h'd-662 ~,a ~- W~KE-TY~E F ir t"/ ........ i.~U~ .... ~'i"~ ........ ~~i'--- · IN ....HRS .............. ._ . W'I'. ON RIT ~.e... x4,~.~. 3..~ ...~/v ~.lZt ^'r .ii O 4t5 F~.d^'~c~ ..................... Pu~ml~.._ .................... r,',.,,,~. AFt VEL. FT./MIN. (D.r.) NOZZLE VEL. ..... Ct..,..? ........ ,,,m, ....... &8. ......... W~'IG/~T Ir L~NE L VIBC. I~% ........ ,~ _...,,2__m_. ~-~..- ..... /.. ' '"H'T,~'WATER L(,16~ J IllJ PI ~ sul~'J Y$ ....................................................................................................... l!:.J., c, ~ '--- ' 3 DAILY PROGIIES~ GF DKItUIIIG WELLS Itl1 MO .... I I · Jzl liAICE-~ F t E'l 140;,191~ ~ ~ ~IN'ION ... f~. TO .......... F~... FT. - IN .......... ~ ...................... 10004 ............ RJR4 _l.. DAIRY PROG~SS OF DIALING WELLS Ple..SI2 All pUt4I~ UUIKI~ ~ A~IKULJdl VII ... FI./. II;l~,I 11~2t f VII .__ .......... I1~-0, .......................... · t ~'~'~i~ .... ........ . . .. ., ......... i~ . .......... =, DAP.Y PROGRESS OF DRILLING WELLS Prl-r42 Prblllld 29. 30. ' - - : "' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hemlock 10,580' 10,575' No DST's were conducted. Fm. Hy Pt'. 10,723' 10,718' ... 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ ,~.~ Area Operations ' Signed ~t'~~ Title Superintendent Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ~ Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherWise Shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21~:.tnc[ieate.wh~ether from ground level (G L) or other elevation (DF KB, etc.) ~ '.- ! .~ :. ., -: · · ·.. .,!'. ~; ~ · , .. ~' . ~ Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and:the location ~)f the cementing tool. Itbm'~7': Method o¢ .Operation' Flowing· Gas Lift· Rod Pump, Hydraulic Pump· Submersible· Water In- jection, Gas.~l~jeet. ion, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA ALASKA ,~,,., AND GAS CONSERVATION CO fISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ,'X GAS~ ~ SUSPENDED ~?; ABANDONED ~ SERVICE L~r~ 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 85-0255 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5o-133-10132-02 4. Location of well at surface 657'S & 1985'E of NW corner Sec. 16, T?N, R9W., S.B.&M. At Top Producing Interval 468'S & 1910'E of NW Corner Sec. 16, TTN, RPW, S.B.&M. At Total Depth 441'8 & 1906'E of NW Corner Sec. 16, T7N, R9W, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. O.L.: 148' K.B. = 168' A-028993 13. Date T.D. Reached I2.11-6-85Date Spudded II 18' Plug12-4-85Back Depth (MD+TVD) 114.12_24_85Date Comp., Susp. or Aband. 17. Total Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 1,005'~ 11,000' 10,960'; 10,955' YES ~ NO ~ NA feet MD 22. Type Electric or Other Logs Run DIL/SFL/SP/OR, DNL/LDT/CAL/OR, SDT/OR, CET, CBL/VDL/CCL/OR CASING, LINER AND CEMENTING RECORD 23. 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 21B-16 11. Field and Pool Swanson River - Hemlock 15. Water Depth, if offshore I 16. No. of Completions NA feet MSLI I 21. Thickness of Permafrost NA CASING SIZE 22" 11-3/4" 7'" 5" WT. PER FT. GRADE 47 J-55 23, 26,29 18 N-80 N-80 SETTING DEPTH MD TOP BOTTOM 26' 35' 22' 2035' 22' 8704' HOLE SIZE *S CEMENTING RECORD AMOUNT PULLED 16" 1600 SKS 11,045'* 9-5/8" 1st 600 sks, 2nd 120~ sks 11,004' 6" 275 sks 9100'-9150' ection cu 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10,606'-10,628'; 10,601'-10,623' 22'-132 JS 10,644'-10,665'; 10,639'-10,660' 21'-126 JS 10,684'-10,714'; 10,679'-10,709' 30'-180 J8 Above 6 - 1/2" JSPF 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8", 2-3/8" 10,547' 10,477' 26. NA ACID, FRACTURE, CEMENT SQUi::EZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First: Production 1-8-86 Date of Test 12-25-85 Flow Tubing Press. 3300 Hours Tested 13.75 casing Pressure .0 IMethod of Operation (Flowing, gas lift, etc,) Flowing PRODUCTION FORIOIL-BBL GAS-MCF TEST PERIOD *] 135 1004 CA LCULATED OIL-BBL GAS-MCF 24-HOUR RATE * 968 ?200 WATER-BBL 0 WATER-BBL 0 CHOKE SIZE GAS-OIL RATIO Various 7438 OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No conventional cores or sidewall cores taken. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE SUB.SURFACE DIRECTIONAL ~URVEY r~UIDANCE r~ONTINUOUS ~"] OO L F E B 2 0 ]986 Alaska ~j. ,. ,, .... ;mssslon Company Well Name Field/Location CHEVRON USA INC. WELL SCU-21B-16 (S16, T7N, R9W) SWANSON RIVER, KENAI, ALASKA Job Reference No. 71222 HEATH Date 05-FEB-1986 Computed By;. OGDEN $CT DIRECTI3NAL SURVEY ~USTDMER LISTIN2 FD~ CHEVRON':USA, IN~. SCU-21B-16 SWANSON RIVER KEN~I. PENINSULA,ALASKA~, SURVEY DATE: 1~-DE2-85 ENGINEER: HEATH METHODS OF~CDIPU'TATIO~ TOOL LOCATION: TANSENTIAL- AVERAGED'DEVIATION ~ND ~ZIMUTM INTERPOLATION: LINEAR' VERTICAL SECTION: qORIZ. DIST. PR3JECTED ONTO A TARGET, AZIMUTH OF NORTH 0 DE~ 0 MIN EAST CDMPUT~TI]q C.qEVRDN USA, I~C. SCU-21B-16 SWANSOq RIVER KE4AI ~ENINSUL~,AL~SK& DATE: 4-FEB-85 INTERPOLATED VALJES FOR EVEN 100 FEET OF COORSE V:RTICAL DOGLEG )EVI~TIO~ ~ZIMUTq SECTION SEVERITY )EG MIN DEG MI~ FEET DEG/IOD TRUE SjB-SEA ME~SURE2 VERTICAL VERTICAL DEPTH DEPT~ DEPTH 0 0 N D 3 E 0.00 O.OD 0 35 N 60 ~D W. 92.07 1.15 0 )6 N 60 25 W 93.05 3,22 1 6 N 9 12 W 93.7~ ~.48 3 ~7 N 13 2 E 98.68 0.46 4 5 N 12 ~ E 105.40 0.15 3 55 N 14 25 E 112.25 0.37 3 51 N 13 11 E 118.87 0.3~ 3 ~8 N 13 5 E 125.41 0.3~ 3 46 N 16 28 E 131.98 0.71 O.OO= 0.00 -168.00 8900.00 8900.01 ~732,0! 90OO.O0 9000,00 3832.00 9100.00 9099.99 ~931.99 9200.30 9199.86 9031.86 9300.00 9299,52 9131,62 9~00.00 9399.37 9231.37 95DO.OD 9499,13 9331,13 9500.00 9598.91 9~39.91 9700.00 9598.68 9530.68 3 14 N 9 35 E 137.84 0.31 3 B N 6 52 E 143.3w 0.35 3 19 N 2 21 E 1~8,90 0.25 3 19 N 4 16 E 154.78 0.27 3 15 N ~ 3 E 160,45 0,29 3 21 N 2 21 E 155.31 0.78 3 35 N 5 11 W 172.19 1.6~ 3 %6 N 9 31 W 178..69 D.40 3 56 N 12 57 W 185.38 O~ED 3 ~1 N 10 50 W 191.89 0.22 9800.00 9798.50 ~630.50 9900.00 9898.3% ~730.34 lOOO0.O0 9998.18 9830.18 10100o00 1~098.01 9930.01 10200.00 10197.85 10029.85 10300,00 10297,57 1~129,67 10~00.00 10397.51 13229.51 10500.00 10497.29 13329.29 10500.00 10597.36 13429.06 IOTDO.O0 10596.83 10528.83 00. DO. 32. OD 1D796.$2 19628.62 O0 10896. G2 10728.42 O0 10928.36 10760.36 3 39 N lO 49 W 198.26 0.40 3 36 N 12 23 W 204.48 1.00 3 39 N 12 53 W 206.46 0.00 108 109 10~ P~GE . ~ . O~TE DF SJRCEY: 1~-05C-85 KELLY BUSHING ELEVATION: 158.00 ~FT ENGINEER: HE~TH M~SURE RECT4N NORTH/ FEE DEPTH 3UL~R S3UTH T O.O0 N 92.07 N 93.05 N 93.74 N 98.58 N 105.40 N 112.25 N 118.87 N 125.~1 N 131.98 N 137, 143, 148, 15~, 160, 166, 172, 178, 185, 191, 198. 204. ~06, CDORD EAST/ FEET 0.0 82.1 83.0 8~.0 83.2 81.7 80.1 78.4 76.9 75.2 84 34 9O 78 45 31 19 ~9 38 89 73.8 72.9 72.5 72.3 71.8 71.5 71.5 72.,5 74.0 75.3 26 ~8 ~.6 76.6 77.9 78.3 INATES WEST HDRIZ. DIST. FEET 0 E 7 W 9 W 9 W 8 W 5 W 2 W 5 W 5 W 0.00 123.~0 124.75 125.93 129.12 133.39 137.91 142.~2 147.1~ 151.92 4 W 7 W 9 W 0 W 0 W 0 W 8 W i W B W DEPARTURE AZIMUTH DEG MIN t 0 0 E ~ 41 44 ~ N 41 45 W' N 41 53 '~ .~ 40 9 W ~ 37 47 ~ N 35 31!' ~ 33 25 t ~ 31 31 ~ N 29 41 ~ 212.55 i 21 7 W 218.83 N 20 51 W 220.83 N 20 46 ~ 156.38 N 28 10 160.84 N 26 58 165.66 N 25. 59 170.83 ~ 25 2 175.78 N Z~ 6 181.02 ~ 23 15 186.~8 ~ 22 .34 192.8~ ~ 22 5 199.62 ~ 21 46 206.17 N 21 26 C~EVR3N USA, I~C. SSJ-21~-15 SWANSON RIVER KENAI PENINSUL&~ALASK~ COMPUT~TI]N ~E~SURED ]EPTH DATE: 4-FEB-86 INTERPOL&TEg VALUES FOR :VE~ 100~ FEET TRUE SJS-SEA VERTICAL VERTI:AL DEPTq DEPTH CgJRSE V~RTICAL DgGLEG 3EVICTION AZIMUTH SECTION SEVERIT~ 3EG ~IN DEG MIN FEET DE~/IOO 0 0 N 0 0 E 0.00 0.0O 0 36 N 60 25 ~ g3.05 3 19 N 2 21 E l~B.gO 0.25 3 3g N 12 53 W 205,~6 O.Og 0.00 -168.00 9DgO.DO gO00.O0 ~832,00 lOOO0.O0 9998.18 9830.18 10932.00 10928.36 1~750.36 P~GE ,-2 ,. DATE DF SURVEY: i~-DEC-B5 KELLY BUSHING ELEVATION: 15B.OO'FT ENGINEER: HE~TH ME&SU'R:D DEPT RECTANSULAR COORDINATES H2RIZ. DEm~RTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DE3 MIN O.DO N O.O0 E 0,00 N O 0 E 93.35 N 83.39 W J2¢.75 N 41 ~5 W 1~8.90 N 72.59 W 165.65 'N 25 59 ~ 206.~6 N 78.35 W 220.83 N 2D 46 ~ CDHPUT~TI3~ D~TE: 4-FEB-86 P~GE , ~3 ,. CHEVRDN'USAt INC. SCJ-21B-15 S&&NSDN RIVER KE~AI PENINSUL~,~L&SK~ INTERPOL&TED VALUES FOR TRUE SJB-SmA MEASURED VERTIC&L VERTICAL 3EPT9 DEPT9 DEPTH CDdRS: )EVI~TID~ AZIMUTH '~EG MIN DES MIN 0.30 0.00 -168.00 58.00 68.00 -100.00 9058.00 9068.00 8900.00 9158.08 9168.00 ~000.00 9~58.31 9268.00 ~100.00 9358.55 9368.00 ~203.00 9~68.80 9458.00 9300.00 9569.02 ~568.00 9~00.00 9559.25 ~668.00 9500.00 9769.~5 ~768.00 ~602.00 0 0 N 0 27 0 ~,3 N 62 2 3 38 N 10 3~ 3 55 N 12 22 3 57 N 13 2~ 3 53 N 1~ 5 3 ~9 N 12 55 3 5~+ N 15 33 3 ZO N ~1 30 9859.62 9868.00 ~700.00 9~69.76 9968.00 9803.00 10069.9~ 10068.00 ~900.00 10170.[1 10168.00 lO00O.O0 10270.26 10268.30 19lOt.OD. 10370.4~ 10368,00 1020 .00 10~70.65 10468.00 10300.00 10570.87 10568.00 10400.00 10571.12 10668.00 10500.00 10771.31 10768.00 10500.00 3 I0 3 14 3 22 3 16 3 23 3 ~6 3 59 3 44 3 ¢4 N 851 N 315 N 5 5 N 2 39 N 1 25 N 8 37 N 13 .45 N 11 1 N 10 ~ EVeN 100 FEET OF 10871,52 10868.00 1DTOO.O0 10932.00 10928.36 10750.36 3 ~2 3 39 VERTICAL D3GLEG SECTION SEVERIT~ FEET 9EG/IOO D.O0 O.O0 0.70 3.01 93.42 0.56 96.57 2.60 103.22 0.45 110.17 0.67 115.82 0.27 123.43 0,52 129.99 0.~5 135.12 0.73 E E E E W W W W N 12 27 W N 12 53 ~ 141.67 0.4~ 147.18 0.19 153.02 0.25 158.73 0.37 154.53 O.l~ 170.41 0.29 175.79 0.27 183.40 D.35 190,06 0.47 195,44 0.15 202.71 0.31 206.46 0.00 DATE OF SURVEY: l~-DEC-85 KELLY BUSHING ELEVATION: 16B.O0'FT ENGINEER: HEATH SUS-SEA DEPTH RECTANSULAR COORDINATES H3RIZ. DEPIRTURE N3RTH/SOU.?H EAST/WEST DIST. IZIIU~H FEET FEET FEET DEG MIN O.DO N O.OD E 0.00 ~ 0 0 E 0.70 N 0.53 W 0.94 N 41 44 2 93.~Z N 83.82 W 125.51 N 41 54 W 96.57 ~ 83.73 W 127.B1 N 40 55 ~ 103.22 N 82.23 W 131.97 N 38 32 W 110.17 N 80.5~ W 135.53 ~ 35 1Z W 116.82 N 78.9~ W 140.99 ~ 3~ 2 ,.' 123.43 N 77.42 W 145.70 ~ 32 5 { 129.99 i~ 75.83 W 150.49 4 30 15 ~ 136.12 N 74.15 W 155.01 ~ 28 34 W 141.57 N 73,20 W 159.47 N 27 19 W 147.18 N 72.66 W 164.14 N 25 16 W 153.02 N 72.41 W 169,29 N 25 19 W 158.73 N 71,9~ W 174.27 N 24 22 ~ 164.53 N 71.58 W 179.~3 N 23 30 ~ 170.~1 N 71.~ W 184.80 N 22 45 ~ 176.79 N 72.21W 190,97 N 22 12 W 183.~0 N 73.57 W 197.60 N 21 '51 W 190.06 N 75.'04 W 204.34 N 21 32 W 196.4~ N 76.25 W 210.72 ~ 21 13 W Z02.71 N 77.53 W 217.03 4 20 55 W 206.~6 N 78.35 W 220.83 t 23 46 W C,tEVRDN USA, INC. SSd-215-15 SWANSON RIVER KENAI PENINSUL~,AL&SK~ CD~PUT&TI]~ INTERPOLATED VALJES FOR M~RKER TOP H-1 TOP H-5 BOTTOM DF LOSGED INTERVAL ~EASJRED DEPTH BELOW KB 10580.00 10580.00 10932.00 D&TE: CHOSEN 4-FEB-85 D~TE OF SURVEY: 1~-DEC-85 . KELLY BUSHING ELEVATION: 15B.O0 FT ENGINEER: HEATH FROM ]RISIN: T V D KB 557' SNL~ SJB-SE~ 10577.11 13676.87 10928.35 10~09.11 13508.~7 10760.36 SJRFA'E LOCATION *T EWL, SEC 16~ TTN R~N RECT&NGJLAR COORdINaTES NDRTH/SDUTq E~ST/~EST 18~.02 N 73.72 190.63 N 75.1~ 206.~5 N 78.35 SCHLUMBEROER O [ RECT I ON'AL SURVEY COMPANY CHEVRON USA INC NELL SCU-21B- 16 FIELD SWANSON RIVER COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00007 '1222 WELL SCU-2 lB- 1 ~ (~16, T7N, R9w) HO R'~-~0NTAL PROJECTION NO~TH ~so 2OO Ioo so -so -IOO SOUTH - ! SO WEST EAST WELL SCU-Z£B-£b (S~6, T7N, R9W) VERTICAL PROJECTION SOUTH - i so -, oo -so o o so ~ oo so zoo 2so ...i...~....,...~...J ....... ~ ........... I...~-..-~ ........... [:...L.~...:.....= ............... 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NORTH II PROJECTION ON VERTICAL PLANE NORTH - SOUTH $CALEO IN VERTICAL OEPTHS HORIZ SCALE = I/S0 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR', WELL NAME AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report y.~.-~,~ ~ -~S/-~__~ ~_~~ Well History Samples ~ud ~og 4/d ..~p / ~/~ C O r e Ch ips Oore Description Registered Survey Plat :.~Incl~nat~on Survey Dr~ll Sram Tast Raports , , TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Corn mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE: ?.- 14- WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001C Street Anchorage, AK 99503 RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: BY: Senders' Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP- 180- 79 (CD-2-85) Printed in U.S.A. TRANSMITTAL ANO ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Commission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE: WELL NAME-. We are sending the material tabulated below. Please acknowledge receipt and return one copy to: . L. Weaver on U.S.A. Inc. 3001CStreet Anchorage, AK 99503 Deve 1 opment/~eo logi st COMPANY: DATE: Oil & Gas Cons. Commission ......... Ancl:or~,.ge Senders' Instructions:- These transmittal sheets are made on NCR {No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.} Please Qse ball-point pen when filling out this form. EXP-180-7g (CD-2-85) Printed in U.S.A. ~ - STATE OF ALASKA ~ ALASKA 6,...... AND GAS CONSERVATION COl,.,.~..,rlISSION ~.. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well [] Workover operation [] Redrill 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 85-0255 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well atsurface 657' S & 1985'E of NW Corner Section 16, TTN, R9W, S.B.&M 8. APl Number 5o- 133-10132-02 9. Unit or Lease Name Soldotna Creek Unit 10. Well No. SCU 21B-16 11. Field and Pool Swanson River -Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L. = 148' K.B. = 168' A-028993 For the Month of. December ,1985 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks T.D. = 11,005'; PBTD = 10,960'; Footage Drilled = 449' 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 55 its 5" 18# N-80 SCC BTC casing and liner hanger = 2299.92' set at 11,004'. 8704'. Cement with 275 sks Cl. "G" at 15.6 PPG. CIP @ 11;00 PM 12/7/85. TOL at 14. Coring resume and brief description NA 15. Logs run and depth where run DIL/SFL/SP/OR CNL/LDT/CAL/OR SDT/OR CET CBL/VDL/CCL/OR 10,995'-9078' 10,995'-9078' 10,995'-9078' 10,951'-8700' 10,942'-8700; ECEIVED 3. N _J 1 1986 Alaska 0it & Gas Cons. Commissio~ Anch0rag0 ,1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforate as follows: 10,714'-10,684' (30'- 180 ½" holes); 10,665'-10,644' (21'- 126 ½" holes); 10,628'-10,606' (22'- 132 ½" holes) 17. I hereby certify that thefygoing is true and correct to the best of my knowledge. J/~,/ Area Operations f/~ SIGNED ~/~/~~"~ TITLE Sur)erintendent DATE ~/~ NOTE--Repo/~n'~-his f~)rr~ is required for each calendar month, regardl;ss of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas4C~ervation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-40 Submit in duplicate TRANSMITTAL .AND ACKNOWLEDGEMENT .OF RECEIPT OF CLASSIFIED MATERIALS · . · DATE: I -g4- C Alaska Oil & (]as - Conservation Commission · Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. - Anchorage, AK 99501-3192 NELL NAME: Ne are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK g950,[ ,.. RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: BY: ' ~.-",' Oil & Gas Senders~ Instructions:- These transmitS1_, s#ee~-sgjre made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted ~terial. Send Ortginal under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when ftlltng out this rom. EXP-180-8 (C0-3-82) Printed in U.S.A. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation (::om mission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attm Mr. W. M. Van Alen WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: BY: Development Ge(flogi st /~JANl~41986 ~ v,,-,,,,,, ~t~ 0il (k ~ ~ns. L;ommls81oll ~mge Senders' Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.} Please use ball-point pen when filling out this form. EXP-180-79 (CD-2-85) Printed in U.S.A. -- STATE OF ALASKA - ALASKA %... AND GAS CONSERVATION CC._~vllSSION · MONTHLY REPORT OF DRILLING AND WORt:COVEI ONS 1. Drilling well [] 2. Name of operator Workover operation [] J A N 0 2 7. Permit No. K Chevron U.S.A. Inc. 8~i'a~0ii & Gas Cons. Con 3. Address 8. APl Number Anchorage P.O. Box 107839, Anchorage, AK 99510 5o_133-10132-02 4. Location of Well at surface 657'S & 1985'E of NW Corner Section 16, TTN, RPW, S.B.&M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.I.. - 1 48' K,B: : 1 6R' A-02. R993 9. Unit or Lease Name Soldotna Creek Unit 10. Well No. SCU 21B-16 11. Field and Pool Swanson River - Hemlock For the Month of. November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth = 10,556'. Drilled 1451'. Began operations at 10:00 A.M. 11-6-85. 13. Casing or liner run and quantities of cement, results of pressure tests NA 14. Coring resume and brief description NA 15. Logs run and depth where run NA .1 6. DST data, perforating data, shows of H2S, miscellaneous data NA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /'7 -/-J~ Area Operations SIGNED _ TITLE Superintendent NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate With the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS DATE: WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 Development ~ologi st ~ DATE: / // 2wq~a u, & G~ Cons commission Alaska ui '' · Anchorage Senders' Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-79 (CD-2-85) Printed in U.S.A. October 24, 1985 ~r. J. L. Weaver Area. Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, Alaska 99510-7065 Re: Soldotna Creek Unit SCU 21B-6 Chevron U.S.A. Inc. Permit No. 85-255 Sur. Loc. 657-'S, 1985'E of _NW er Sec. 16, T7N, R9W, SM. Btmhole Loc. 462'S, 1896'E of MW er Sec. 16, T7~, R9W, SM. Dear Mr. Weaver: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the~.Commission may witness testing before drilling below the shoe of the conductor pipe. Very t~-lv__vours, ~ Chairman o f Alaska Oil and Gas Conservation Commission be Enclosure CC: Department of Fish & Game, Habitat Section W/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Chevron Land Departmem Chevron U.S.A. Inc. 3001 C Stree[, Anchorage, AK 99510 Mail Address: P.O. Box 107839, Anchorage, AK 99510 Phone 1907) 786-6600 October 21, 1985 APPLICATION FOR PERMIT TO DRH,L SCU 21B-16, SOLDOTNA CREEK UNIT Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Sirs: Enclosed please find an Application for Permit to Drill from Chevron U.S.A. Inc. for the above referenced well. This application is actually to allow a redrill of the SCU 21A-16 producing well to a new bottomhole location within 100 feet of the original SCU 21-16 location. Chevron respectfully requests an expedited review of this application since a revised operations program would schedule spudding on or about October 25, 1985. Should you have any questions or concerns with this application please do not hesitate to call me at (907) 786-6665. JDA:fm Enclosure Very truly yours, RECEIVED ocr 0il 8, Gas Cor~s. Commission STATE OF ALASKA ALASKA O1EAND GAS CONSERVATION COrtm~IISSION P£RMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL 1~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE~ MULTIPLE ZONE 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 657'S & 1985'E of NW Corner Section 16, TTN, R9W, S.B.&M. At top of proposed producing interval +189' N & +89'W of surface location +195'N & +89'W of surface location 5. Elevation in feet (indicate KB, DF etc.) G.L.=148' K.B. = 168' 6. Lease designation and serial no. A-028993, 9. Unit or lease name Soldotna Creek Unit 10. Well number SCU 21B-16 11. Field and pool Swanson River, Hemlock 12. Bond information (see 20 AAC 25.025) N/A - 20 AAC 25.025(e) Type Surety and/or number Amount 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 16.5 miles NE miles 468' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease TVD = 11,000' MD = l l,010~e"t 2560 19. If deviated {see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 9100 feet. MAXIMUM HOLE ANGLE 4 o {see 20 AAC 25.035 lc) {2) 15. Distance to nearest drilling or completed TVI)vell SOU Il-Id 1550feet 18. Approximate spud date October 2 5, 1985 3820 psig@ 0' Surface 4880 psig@.l 1,00C}t. ]~]~EK(TV D) 121 SIZE j Hole Casing ! 122" 6-6 1/81' $" Weight 18# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH MD TOP TVD I Window 8800' ~ ~ 8800' MD BOTTOM TVD 35' I 35' 2035' i 2035' 9540'19540' 11,010'Ii1,000' t QUANTITY OF CEMENT (include stage data) Existing Existing Existing 150 sks See Attached Drilling Program. RECEIVED OCT 2 Alaska Oil & Gas Cons, Commissiori Anchorage 23. I hereby certi~ that ~e foregoing is true and correct to the best of my knowledge ~.,~_~~~/~~_~.__~~/} Area Operations SIGNED TITLE Superintendent DATE The space ~ro~ f'8~ Commission use (/~,, CONDITIONS OF APPROVAL Samples required []YES J~.,.N 0 Permit number APPROVED BY Form 10-401 I:~, '~_1 _~/"~ Mud Icg required []YES ~.NO Approval date Directional Survey required { APl number ~,.YES []NO .50--/,f~ -/C')/~?.~-0'1.~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 24, 1985 by order of the Commission Submit in triplicate Proposal For Well Operations PRO 316-1 Well SCU 21B-16 (Redrill of 21A-1.6) Well: SCU 21A-16 (to be redesignated 21B-16 upon kicking off) Field: Swanson River Surface Location: 657'S and 1985'E of the NW corner of Section 16, T7N, R9W, SB&M Original Bottomhole Location: 21A-16 Redrill Bottomhole Location: 11054' MD; 103'N and 103'W from the surface location. 10910' MD; 72'S and 133'W from the surface location. Proposed 21B-16 Bottomhole Target: A 50' to 150' radius extending due west, clockwise to due east from the original bottomhole location (see attached plat). Elevation: 148' GL 168' KB (original) Present Status: T.D.: 10,910 M.D. PBTD: 10,836' Casing: 22" cond. cemt'd. ~ 35'. 11-3/4", 47#, J55 cmt'd. ~ 2035'. 7", 23-29#, N80 & Pll0, cmt'd. ~ 11045'. Window milled in 7" casing from 9580' to 9540'. Liner: 5", 18#, Pll0 & NS0 cmt'd. ~ 10908' (top at 9336'). Perforations: Tubing: Junk: 4 - 3" JHPF 10770- 10725 (H4-5) 10710 - 10702 (LH3) 10697-10685 (UH3) 10670- 10644 (H2) See attached tubing detail. None -APpRoVED PROGRAM L. J. Porter' Blowout Prevention: Potential Problems: 1. Gas: Gas may be encountered at any time within the Hemlock. o Lost Circulation: Most likely in the Hemlock. be minimized when running the liner. Sur, ge._pressure should ' ECEIVED oct /ilaSka 0il & Gas Cons. COmrnissior~ Anchorage e Water: High pressure fresh water_ sands above the Hemlock are common. Following is a list of mud weights used to drill through it: SCU 21-16 12.8 ppg SCU 21A-16 11.4 ppg SCU 43A-4 13.1 ppg -SCU 31A-16 11.9 ppg It is felt that 11.4 ppg mud will be sufficient to drill these sands in 21B-16. Precautions: Surge pressure should be monitored throughout the Hemlock to prevent lost circulation. Pit volume should also be carefully monitored for fresh water flows. Coal seams will most likely be encountered. Pipe should not be stationary for any longer than connection time. Maximum Anticipated Formation Pressure: 4880 PSI The water sands above the Hemlock are estimated to have an 11.4 ppg pressure gradient. Maximum Anticipated Surface Pressure: 3820 PSI Blowout Prevention Equipment: API publication 53. Class III, 5000 PSI as per Estimated Correlations: Marker Subsea Vertical K.O.P. 9082' Hemlock Top -10610' 10758' T.D. -10730' 10878' Based upon a ground level elevation of 148'. PROGRA,M / ~~~j po r ~e/r~,j//?.~ . . e Se . . . . PROGRAM ""'~ Prior to moving in the rig, complete the following: A. Install dummy valves as required in all gas lift mandrels. B. Open .the XA sleeve at 10,632'. C. Install a BPV. . Move in and rig up the workover rig. PROGRAM/ Remove the BPV and kill the well with 9.6 PPG workover fluid per the attached program. ~. Install the BPV, and nipple down the tree. Nipple up a Class III 5000 PSI BOP stack per API RP 53. Test the rams and manifold to 5000 PSI and the annular to 3500 PSI. The AOGCC and BLM to witness and must have 24 hours notice. Release the three (3) Baker "FH" packers. Pull Out of the hole with the 2-7/8" tubing and associated production equipment (see the attached detail). Clean and test all gas lift mandrels. Install dummy valves in all mandrels. Redress packers. Pick up and trip in the hole with a 6-1/8" bit, 4-3/4" drill collars, and 3~" drill pipe; and clean out to the top of the liner at 9336'. NOTE: If the 6-1/8" bit will not go, run a 6" bit. Pick up and trip in the hole with a 4-1/8" bit, 2-7/8" drill pipe, and 3~" drill pipe; and clean out to PBTD. Circulate the well clean. Trip in the hole with open ended drill pipe to 10,836' or clean out depth. Equalize a balanced plug with 50 sacks of Class "G" cement, retarded as required for pumping time and temperature, mixed to a slurry density of 15.8 PPG. Pull up to 10,450', and reverse out excess cement. The AOGCC and BLM may witness plugging, and they will need 24 hours notice. Pull out of the hole to 9436'. Equalize a balanced plug with 50 sacks of Class "G" cement, retarded as required for pumping time and temperature, mixed to a slurry density of 15.8 PPG. Pull to 9180' and reverse out excess cement. 10. Pull out of the hole and WOC. 11. Trip in the hole with a bit, and test the top of the plug with 15,000 lbs. set down weight. 12. Pressure test the casing to 3000 PSI. If the casing leaks, locate the leak and squeeze as required. 13. When the top plug has been tested satisfactorily, the designation changes to 21B-16. 14. Trip in the hole with a 7" casing section mill, and~e.-~-~ r--r-~-~.. _mi~ .~-~vindow in the 7" casing from 9100' to 9150'. Circulate the well with §l~*du"s~~[-~Dto clean Alaska Oil & Gas Cons, A. nchora,~e 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. the well. Round trip - change section arms to rotary mill tooth arms. Underream the milled section from 9100'-9150' to 9-3/4". Circulate the well clean. Trip in the hole with open ended drill pipe to 9180' and equalize a balanced plug with 50 sacks Class "G" cement, retarded as required, mixed to a slurry density of 17.0 PPG with 0% free water and 100 cc or less fluid loss. Pull up to 9000', and reverse out excess cement. Down squeeze the top of the cement to approximately 9050' or until 1500 PSI surface pressure is attained. WOC until a compressive strength of 2500 PSI has been achieved prior to re- entering the well. Trip in the hole with a bit, 4-3/4" drill collars, and.3{" drill pipe. Drill out the cement plug to 9110'. Pick up and trip in the hole with a side-track bit, bent sub, motor, orientation sub, and remainder to BHA on 3 {" drill pipe. Orient and side track the new well due north to a TVD of 11,000' 100' section distance from the KOP (see attached plats). Rig up wireline loggers, and run logs per the attached "Formation Evaluation Program" and the wellsite geologist. Condition the hole for liner operations. Rabbit drill pipe. Rig up and run the 5" 18# N-80 Spl clr BTC casing as follows: A. Float shoe on bottom. B. Float collar one' joint above the shoe. C. Plug landing collar two joints above the shoe. D. 2200' 5" 18# N-80 liner. E. Hydraulic set liner hanger. F. Tie back extension. Run the liner on 3{" drill pipe. Circulate two "bottoms up" prior to cementing. Cement the 5" liner as follows: A. Preflush B. Sufficient Class "G" + friction reducers, retarders, and water loss control for pumping time, temperature, less than 50 cc water loss, and 0 free water. C. Spacer D. Displace with drilling fluid and bump the plug to 2000 PSI over displacing pressure. E. Reciprocate the liner in 10'-20' strokes until just before the plug bumps. Pull out of the hole with liner setting tool. Do not reverse cement, and keep the hole full. WOC until it has achieved a compressive strength of 2500 PSI prior to re- entering the well. RECEIVED 41aska Oil & Gas 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. 36. 37. Pick up and trip in the hole with a bit, tandem scrapers, 4-3/4" drill collars, and 3 ½" drill pipe. Clean out to the top of the liner. Pick up and trip in the hole with a 4-1/8" mill, drill collars, sufficient 2-7/8" drill pipe on 3~" drill pipe and clean out to the float collar at 10,960'+/-. Test to 2000 PSI. - Circulate the well clean. Rig up Schlumberger and run a CET log from PBTD to the top of the liner. Run a 7" RTTS packer and test valve on 3~" drill pipe with a cushion 2000 PSI less than the hydrostatic at the liner top. ~. Set the packer at 8800' and perform a WSO test on the liner top. Squeeze as determined by the CET and liner top test. Clean out to PBTD with bits, tandem casing scrapers as required. Trip in the hole to PBTD and displace the hole with lease water. Pull out of the hole and lay down the drill strings. · Complete as dictated by the log evaluation. Release the rig. Return the well to production. V.W. ANGELL/M.R' RIEKEN VWA:mw 8/23/85 -.ApPROvED PROGRAM ~. J. P~rt~r J~.__~ /0" 5000 ~-* fO" 5000 /0".5000 psi BLIND PIPE ~"' /0" ~000 pst ! 6"- 5000 ~sl ~."..~¢C(~ ~i ," 7" C~SlNG I' ' ' ~ I ,, _' ~, ~ ~ ~ · . ..' -. -. ~,-.m2" - · '-..~? -. · · . · ~-- .. ~- -. ..... . · CHEVRON U.S.A. SCU 21B-I~ Notes · All values in feet. Depths shown are TVO. Closure: t45 ft at N 44 deg 28 mir W Bottom hole: TVO 10743 TMD 10745 Magnetic declination: 25 dog E ! HORIZONTAL VIEN CHEVRON U.S.A. SWANSON RIVER FIELD WELL SCU 21- 1RADIUS OF CURVATURE !GYROSCOPIC SURVEY i ! !SCALE' ! inch = 50 feet I !DRAWN ' 6-t9-85 l Original Well Red,ill Well I I 1 -Planned Redrill - , iJ Alaska Oil & Gas .i . o [ ..... r .......[ ...... ~__ _ VERTICAL SECTION i I ~ CHEVRON U.S.A. I I i SWANSON RIVER FIELD WELL SCU 21- o.~ ~-- ....... ? . . ~ , RADIUS OF CURVATURE t.3o.~'- .... i ..... ? ......... , GYROSCOPIC SURVEY i ,' [ ;SCALE', 1 inch = 1300 feet i.95 F------__2_._] ........ ~---_L~ DRAWN · 6-19-85 2.60 i ~ ,' , | , 3.25i .... ~ ........ ! i, ... f_ 3.90 - ~ ~ ~ ..... '. I '_ ~ ~ Plan ed 6,50· - ~ ~ (fi x 7.~s _ ~ .__1 ..... I '-' t-- tooo~ ~ ~.8o ..... ~ 8.45 .......... ~ ........... r __ _ _~ _~.__ . TVD ~ ........ ~ tt.70 .......................... -0.65 0 0.65 t.30 t.~ ~.60 3.2~ 3.90 4. Departure 4121~ ~1744~ S,41 g.4Y-- 9840' WI N DOW ISlQ" K.8. TO TUBING HANGER TUBING HANGER W/ CASASCO . 2~' G.S~' N-BO TUBING PUPS r~ 21.21' 43 JTS. 2~b" 6.~N-80 TU61NG 1350.50' CAMCO 41 CAMCO CAMCO I? CAMCO II CAMCO I0 CAMCO I0 MM MANOREL JTS. 2.~' B.$~N-80 TUBING MM MANDREL JTS. 2z/~"S.$1rN-80 TUBING MM MANDREL_ JTS. 2~.4'' B.S~ N.-BO TUBING MM MANOREL ~ · J TS. M 2A,~il~ R6~' N- B 0 TUBING MM JT$. Z~'6.5~ N-SO TUBING MM MANDREL JTS. 2~' 6.5~ N-80 TUBING CAMCO MM MANDREL 40 JTS. 2~' 6.$~ N-80 TUBING CAMCO ~'M MANOREL 39 JTS. 2~" 6.S'~N®60 TUBLNG CAMCO MM MANOREL 39 JTS. 2~" a.$a'N-BO TUBING CAMCO MM MANO~E~ ~o JTS. ~' · ~-ao ~Ua~N~ ~MCO ~M ~ 'Z~ 2~' X-OV[~ 12.98' 12 87.69' 13.04' 12.87' 533.92' $45.4~: 13.02 31'fl;.O7 13.21 314.07 13.2~..'. 12 56.26' 13. bo' 1224.8.7 13.0 1211.81 13.C 314.0 I 31.41' i. io' 44 JTS. 2~/~'4.7~ N' 80 TUBING 1377.20' 2~°OTIS 'XA' SLEEVE 2H%5~ lBd BAKER 'FH" PACKER OTIS 'S' NIPPLEj Position 44 ~ 2~t BLAST JTS. (20.33' & I0.01' 1 OTiS · XA' SLEEVE BROWN ~CC' SAFETY JT. 2~,5', 18,lrBAKER'FH- PACKER OTIS "S' NIPPLE~ Position ~3 2 2~'k' aLAS? J TS. (20.23' &, 9.99°1 OTIS 'XA' SLEEVE BROWN 'CC' SAFETY JT. 2~,~,~5', lBJ BAKER 'FH" PACKER 2~'OTIS 'S' NIPPLEt Position~2 I BLAST JT. 2:~4*CAMCO '0' HI PPLE I BLAST JT. PROGRAM / Alaska Oil & Gas Cons. Com~ Anchorage I.$:~ 1.41~ 5.4'/" 1.54' 3o.z 2.9o' 1.42" 5.46' I.~2' 20.32' °90' 20.00' S CU 21A-16 ~s,~lNO & TUBING 'DETAIL SECTION 16 T. 7N,,R. BW. · i i 'l l l J' l i LL8 ~ ! Ir I I zsA-t~, I FORMATION EVALUATION OPEN HOLE LOGGING: Ae Wireline logging company as specified by Area Production Engineer. Obtain ~ gal. of drilling fluid prior to pulling out of the hole for logs. B. DIL-SFL-SP-GR from TD - 9100'. Ce le 2" = 100' Arithmetic linear 0 - 50 ohmmeter resistivity scale, 0- 1000 millimhos conductivity scale and 100 MV (10 MV per division) SP scale. 5" = 100' Ligarithmic .2 to 2000 ohmmeter resistivity scale and 100 MV SP scale. Display SP and GR in track 1. - CNL-LDT-SP-GR from TD - 9100' le e me Neutron scale of .60 sandstone porosity units. Density porosity scale of 0 - 60 units plus density scale of 1.65 to 2.65 grams per cc. SP and GR to be displayed in track 1. GR scale of 0 - 100 API units. SP scale of 10 +/- MV. SP may be played from prior log. Record at 1.2" sampling rate. Display LDT-CNL as two logs. A. Log 1: B. Log2: Display SP-GR-CAL in track 1. Display LDT-CNL (porosity units 0 - 60%) correction curve in tracts 2, 3, and 4. Display SP-GR-CAL in track 1. Display PE curve, tension, and LDT (1.65 - 2.65 gms/cc) in tracks 2, 3, and 4. D. BHC-Sonic-GR-CAL from TD - 9100'. le 2. 3. 4. Sonic scale of 50 - 150 microseconds per foot. SP and GR to be displayed in track 1. Record in combination with DIL-SFL. GR scale 0 - 100 API units. SP scale 10 +/- MV. E. Use heavy pen weight when making film. Fe Ge Compute Cyberlook at wellsite. RW = .33 ~ 68OF N=2 M =1.73 A=1.13 Have CST available if needed. RECr IVED OCT Alaska Oi~ & Gas Cons. CommissJor~ Anchorage II. CASED HOLE LOGGING: A. CET- Run with 2000 psi surface pressure on well. B. Long and short spaced neutron log 1. Normalize the two curves in the fresh water sands above the Hemlock. 2. Record the GR in track 1. VWA:mw 816185 RECEIVED oc'r 2 ~ ~9115 Alaska 0il & Gas Cons. Commission Anchora.ge DRILLING FLUIDS PROGRAM SCU 21A-16/SCU 21B-16 Swanson River Field MUD SYSTEM: Fresh Water FLUID PROPERTIES: Type Weight (ppg) Viscosity - sec./qt., API Fluid loss - cc, API Plastic VIS. - CPS Yield Point- lb./100 ft2 Gel lb/100 ft2 (10 min) ph Solids - Percent by Vol. P & A 21A-16 Fresh Water Gel 9.6- 10.0 36 - 50 15 or less 5-9 12 - 15 15 - 20 8.5 10 Redrill 21B-16 Lignosulfonate 11.0 ppg 40 15' 12 - 16 8-13 4-10 9.5'- 11.0 13- 16 * Less than 10 through the Hemlock. RECEIVED Alaska 0il i Gas Cons. Commission Anchorage I-- 9000 _ ~ ........................ .~ I0,000 ....... .._ '-'.. /0, 500 ~ ~ ~-~-= ~ , . STATE OF ALASKA ALASKA O~--AN D GAS CONSERVATION COM,~iSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 75-33 3. Address' P,O, Box 107839, Anchorage, Alaska 99510 4. Location of Well At Surface: 657'S & 1985'E of NW Corner Section 16, T7N, Rgw, 8. APl Number 50- 133-10132-01 9. Unit or Lease Name Soldotna Creek Unit SB&M. At Top Prod. Interval: 28'8 & 13YW of Surface Location At TD: 72'S & 13YW of Surface Location. .5. Elevation in feet (indicate KB, DF, etc.) GL= 148' KB= 168' Lease Designation and Serial No. A-02899fl $' 10. Well Number SCU 21A-16 11. Field and Pool Swanson River = Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon r~ Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. .... Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of sta~ti~g~"'~/ proposed work, for Abandonment see 20 AAC 25.105-170).' . 1. Install back pressure valve. 'ql°ekaOil8 2. Move in and rig up rig. ' 3. Remove the back pressure valve and kill the well. 4. Install the back pressure valve and nipple down the tree. Nipple up the Class III - 5000 P BOPE and test. 5. Remove the back pressure valve. 6. Release the packers and pull the production tubing and associated equipment. 7. Clean out to PBTD. 8. Trip in the hole to PBTD with open ended pipe. 8et a cement plug across perforations (10,700'- I0,644')from 10,836'- 10,500'. 9. Pull out of the hole to 9436'. 8et a 200' balanced cement plug from 100' below the 5" liner top to 100' above the liner top. 10. WOC. 11. Trip in the hole with a bit and test the cement plug from 9436' - 9236' with 15,00 LBS. of set down weight. 12. Pressure test the 7" casing to 3000 PSI and prepare to sidetrack and redrill well SCU 21B-16. We anticipate starting this work October 1, 1985. /t,'/~/b.- : 71//~' /-~.,':)/~'~' tlc' -- //,g// ]:,EP~Fz ! I,O,d'-/q-?) 14. I hereby certify t~~~rue and correct to the best of my knowledge. STil~e~:~ace b Ti,,e Area Engineer Date Conditions of Approval, if any: It¥ LOH~I[ C. S~ITlt Approved by. COMMISSION ER Approved Co, p¥ Return~J By Order of the Commission Oa,e 5 Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CHECK LIST FOR NEW WELL PERMITS Company t,, ~-''~'r''~'~:~- Lease & Well No. ~C~--,~d ~f/ ~ //~ ITEM APPROVE DATE (.2 thru 8) (8) (9 thru 12) (10 and 12) (4) Ca s g ~4~.~,~z~ ~,n-~f,~ (13 t~ru 21) (22 thru 26) YES the permit fee attached .......................................... ~ ',~ 2. Is well to be located in a defined pool ............................. ,,~ .... 3. Is well located proper distance from property line .................. · 4. Is well located proper distance from other wells .................... '<' 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party .................................. 8. e 10. 11. 12. 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. NO REMARKS 27. Can permit be approved before ten-day wait ..... eeeeeeeeeeeee~eeeeeeeee.e.~"~.. Does operator have a bond in force ..................... .~[ Is a conservation order needed ...................................... Is administrative approval needed ............................... ,... Is the lease number appropriate ............................. . ........ ,,..?...-",,. Is conductor string provided ....................................... '. Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~ Will surface casing protect fresh water zones ....................... ~_~ Will all casing give adequate safety in collapse, tension and burst...~ Is this well to be kicked off from an exiSting wellbore ........... ~ Is old wellbore abandonment procedure included on 10-403 ..~ ..... i Is adequate wellbore separation proposed ............................ ~ Is diverter system required " ~ · Are necessary diagrams of ~ BOP equipment attached . . ~,~ Does BOPE have sufficient pressure rating - Test to $~,~O ~i~ i. Does the choke manifold comply w/A?I RP-53 (Feb.78) .................. Is the presence of H2S gas probable .................................., ~ Additional requirement s ............................................. ~ Additional Remarks: Geology: En~ineerin~: HWK ~ LCS ~ WVA ~ MTM ~,.~ HJH ~7~ .rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , ..... Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · bis T~PE VERIFICATION blSTI~G RECEIVED FEB 2 0 1986 Alaska Uh bVP O,~O,H02 VERIEICATION LISTING PAGE ~* REEL HEADER ** S~]RV ICE N'A~E :GCT ]ATE :86/02/ 5 ]RIGIN : REEL NAME IR DEPTH ~QNTINUATION ~ ~REVIOUS REEL ~O~MENTS :SCNI,,U~BERGER ~ELL SERVICES PROPRIETARY FIEI,.,D TAPE ~* TAPE HEAOER ** SERVICE NAME :GET 9ATE :86/02/ 5 3~iGIN :0000 rAPE NAME : 1222 CONTINUATION # :01 PREVIOUS TAPE : ~OMMENTS ~SCHLUMB~RGER ~ELL SERVICES PROPRIETARY FIELD TAPE ** FILE HEADER ** FILE NAME :GCT ,001 SERVICE NAME VERSION # DATE : MAXIM[]~ LENGTH : 1024 FILE TYPE PREVIOUS FILM ** iNFORMaTION RECORDS ~NE~ CDNTENTS [}NIT TYPE CATE SIZE CODE; IIII IIII !III I~II Ifil ~N : CHEVRON USA INC 000 000 015 065 ~ : SCU-21F-3 6 000 000 010 065 FN : SWANSON P,I V ~;R 000 000 01~ 065 RANG: 9w 000 000 002 065 tOWN: 7N 000 000 002 065 SECT: 16 000 000 002 065 COU~J: KF, N~I 000 000 005 065 STAT: ~[.,ASK A 000 000 006 065 ~TRY: USA 000 000 OOB 065 ~NEM CONTENTS UNIT ~YPE CATE SIZE CODE PRES: E 000 000 00! ** COMMENTS ** ************************************************************************** O65 LVP OIO,H02 VERIFICATION' LISTING PAGE 2 * SCHLUMBERGER * ALASKA CO~P[ITING CENTER ************************************************************************** COMPANY = C EVRDN USA, I. NC, WEI~[, : 5C[1-21B-'16 FIELD - SWANSON COUNTY = KENAI PENINSULA ALASKA m ALASKA JOB NUMBER AT ACC: 71222 RUN #ONE. DATE BOGGED: 14-DEC-85 LOP: ~, O~DEN CASING = 7.0" 0 9100,0' - CASING : 5.0" @ 10960,0' - BIT SIZE = 6.0" TO: 11005,0' BIT SIZE = 6,0" TO 11005,0' AZIMUTH OF PLANNED VE~T£CAL PLANE: 0 SURFACE 50CATION: 657' SNL. 1985' EW[,. SEC 16. TTN. Rgw * , , , :~ , , , , , GYRO CONTINUOUS TOO[, ~VP 010.H02 VERIFICATION bISTTNG PAGE 3 , * DEFINITIONS~ * HLAZ= AZIMUTH * DE¥I= DEVIATIDN * GDEP= GYRO DEPTH * VD-EP~ TRUE VERTICAL DEPTH * NSDR= NORTH OR SOUTH DEPARTURE , EWDR~ EAST OR WEST DEPARTURE * DGL = DOG LEG (CURVATURE OF THE ~* OATA FORMAT RECORD ** ~NTRY SHOCKS TYPE SIZE REPR CODE ENTRY 2 i 6.6 0 4 ! 66 255 8 4 73 60 9 4 65 ,lin 16 ~. 66 1 0 ~. 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl AP1 APl. API FILE SIZE SPb REPR ID DEPT GDEP DEVI LUS EWDR LOS DGL [,OS ORDER # LOG TYPE CLASS MOD NO, CODE ~ oo ooo oo o o ~ 1 ~, ooooooooooooo o ~'~ ~ ooo oo o o 4 t ~,oooooooooooooo ~ oo ooo oo o o 4 ~ 68 oooooooooooooo ~e~ oo ooo oo o o 4 ~ 6~ oooooooooooooo ~ 99 6~o ~l o o ~ 1 6~ oooooooooooooo FT O0 000 O0 0 0 4 I 68 00000000000000 ~T oo oo0 O0 o 0 ¢ 1 ~8 oooooooooooooo ~'T oo ooo oo (, o 4 ~ ~8 oooooooooooooo DATA VP.O!.O,H02 VEt~IFICATiON [~!$TING PAGe: 4 .EPT 65536,5000 (,LEP g989,9941 VDEP 8990,0000 HGAZ 298, 192 '~:Vl 0,6024 ~;~SDR 93,0000 EW[)~ -83,0000 DGL 1, 609 .~:PT 65600,0000 GO~P 91~4,496~. VDEP 9~34,4746 Hb~Z ~,6748 ,.. ~ M- .~ ~EVI 2 , .3'/~ (~ .. 5DR 94,7612 EWD~ 84,0269 [)G[~ 4,'4353 ~EPT 65700 0000 G[)EP q374,8945 V~)~.~P 9174,3223 abaZ 1~.b698 '~ ) .. ;E[T 65800,0000 G[)EiP 10! 25,1953 VDEP 10123,1660 HGAZ 5,0166 )EVI 3,234.6 NSDR 156,2~49 EWDR -72,~794 DGB 0'5670 )EPT 65960 0000 G[)EP 10931.994~ VDEP '10~28'3496 Hh~Z 347.2548 )EVI 3:6673 NSDR 206,4622 EWDR 78,3496 DGL 1,0025 FILE TRAILER ** ~ILE ~ ~E IGCT ,001 ~F.,RVICE NA~E ~ERSION ~ : IAXI,,IU~ LENGTH : 1024 4EXT FIbE NA~E ; EOF TAPE TRAILER ~ER'VICE N h..~E :GCT )I%TE ~86/02/ 5 ]RIGIN :0000 ~APE NA~E 11222 20NTINUATI[)H ~ :01 ~EXT TAPE N.A~F : 20~E~TS :SCHLUmbERGER ~EI,[., S~3RVIC~.;S PROPRIETARY FIEbD TAPE g* REEL SERVICE NAME :GCT )ATE ~86/02/ 5 3RIGIN : gEEL ~A~E :R DEPTM qEXT RF~L NAiF COM~ENTS :SCHLU~-iB~;~GER ~ELL SERVICES PR[)PRI~TARY FIEL~ ~APE e~e~oqouV ~O~SS~LUL~O,9 'SUO,9 se~ ~ I!0 e>iseiV ~';: .... SCHLUMB ERGE R ..... LiS TAPE W~R'IFIC~TiON LISTING LVo ....010 HO2 V~RIFICAT!DN LiST!NS o,~,',,,~E 1 ~';~-.,- REEL H~ADER SERVICE NAME :EDIT DATE :85/12/18 ,3R ]:GIN : REEL NAME :!49741 CONTINUATION ,~ :01 PREVIOUS REEL : COMMENTS :SCHLUMBERGER WELL SERVICES PROPRI ETAR ¥ H-'--,- TAPE HEADER ...... .,..,. SERVICE NAME :EDIT DATE :85/12/18 ORIGIN :0000 TAPE N,~ME :1057 CONTINUATION ~ :01 PREVIOUS 'TAPE : CO~MENTS :SCHLd~:~E~GE2 WELL SERV.iCES PRSPRI:.'=~'A, R¥ Hq= FILE HEADER FILE N,4 M'E :EDIT .001 SERVICE NA~E : VERSION ~ : DATE : M,~XIM~JM LENGTH : :ILE TYPE : PREViGLJS FILE : ~:-'-~,-' INFORMATION RECORDS H~:-' MNEM CONT.ENTS CN : CHEVRON USA INC NN : SCU-ZIB-15 FN : SWANSON RIVER RANG: 9W TORN: TN SECT: 16 CDUN: KENAZ STAT: AL~SK,~ CT R Y: US .~ MN:M CONT_=NT S PRES: F =',~ =:~ C ,] M M: N T S ...... FIELD TAPE FIEL'D TAP'E UNIT TYPE CATE SIZE CODE OOO 000 918 065 000 000 010 055 ODD 000 01~ 065 000 000 002 065 OO~ 000 002 055 000 000 002 065 000 000 006 065 OOO 000 005 065 OOO OOO 003 055 UNIT TY~:. C~T=~ SIZE CODE 00 O 001 055 LV? OlO.H02 VERifICaTiON L.ISTINS PAGE '2 S C H L U ',~ S E R G E R ALASKA COMPUTING CENTER CDMPANY : CHEVRON US.A, INC WELL : Sgd-Z15-16 FIELD : SWANSON RIVER COUNTY = KEN~i STATE = &LAS~A JOB NUMBER AT A~C: 71057 RUN ~1, DATE LOGGED: 5-DEC-B5 LOP: L. B.. CUDNEY CASING : 7.000" 'TYPE FLUZO = LIGN3 DENSITY = 12.B VISCOSITY = 56.0 S PH = FLUID L3SS : 9100' ~ I T .S I Z E RM AT ~M:T 11005 ' : .730 : . 5 ~. 0 60.0 172. OF MATRIX SANDSTONE LVm 010.H02 VERIFICATION LISTiN& PAGE 3 SaSE LOG: SCHLUMBE:RC, ER LOGS .INCLUDED WITH 'THIS MAGNETIC TAPE: D~AL INDU'CTIDN SPHERICALLY FOCUSE2 L'3~ (OIL) DAT.4 4V,~iLABLE: 10990' TO 86'95' LITHO DENSITY COMPEN'SATEO LOS (LDT) COMPENSATED NEUTRON LOG (LOT) D'AT4 aVAILABLE: 109'9Z' T~. 9078' SDT DIGIT~.L SONIC D~T,~ INCLUOSD SN THI,S TAPE -- FROM FIELD ANALOG mR~3CESSiNG: LVP 010.H02 VERIFICATION LIS'TINS MDT.,SOT - MUD D~LTA T LSDT,SDT - LSNG SPACE DELTA T (8 - 10 .FT) LDTL,SOT - LONG SPAC~ DELTA T LONG (10 - !Z FT) FRDM FieLD SOT PROCESSING: DTCO.SDT - DELTA T COMPRESSZgNAL DTSM.SDT - DELTA T' SHEAR DTST,SOT - D~LTA T STONELY ACE,SOT - &VG CD~PRESS,IgNAL ENERGY AS~,SDT - AVG SHEAR ENERGY ASTE.SOT - AVG STSN~L¥ ENERGY THERE WERE ~ M,&ZN PASSES FOR THE SOT, 'THEREFOR THE CURVE EXTENSIONS ARE .SDI~ .SOD, .SD3, AND .SD~ T!] AVOiO CONFUSi~N AND TD INCLUDE ALL THE DAT~ AV.~iLABLE. N~ ¥ ~- -,- ~- -,- -,- -,- ,,- -,- -,- ~- ..- -,. ;~ -,- .,- -,- -,- -~ -,- :'~ D~~ :~ ',- '~ ~;- ',' '~ :,' .,' ',. ',- ',~ ','',' ¥ ',' ,," ',- ',' ',' ',' ~' '.~ ~ DATA FORMAT RECORO $:X ENTRY BLOCKS 'TYDE SIZE REPR CODE ENTRY 2 1 66 O ~ 1 66 1 ~ 4 73 50 9 ~ 65 .lin 16 1 66 1 0 1 66 0 D~TUM SPECIFICATION BLgCKS MNEM SEqVICE SERVICE UNIT 4Pl &Pl AP1 APZ FILE SIZE SPL REPR PROCESS LVP OlO.H02 YERI~ICATiON LISTING P4GE 5 OEPT SFLU ILD ILM GR C~LI RHS5 DRHO NR,~T RNRA NPqi PEg NCNL PC NL QSS QLS SR LSDT LOlL OTC~ DTSH DTS'T ~S~ ~STE GR MDT LSDT LDTL DTC~ DTSM DTST ACE ASTE MDT LSDT LDTL DTCO 3TSM DTST 4C: AS5 ASTE MDT LSDT LDTL DTC9 ID DZL OIL OIL O I L LOT LDT LDT L O T L DT LOT L O'T LOT LDT LDT LOT L D T S 01 SD1 .SO1 SD1 SC1 SC1 S ~ 1 SC1 SC1 SCi S02 SD2 SD2 SO2 SC2 SC2 SC2 SC2 SC2 SC2 S D3 SO3 SD3 SO3 SC3 SC3 SC3 SC3 SC3 SC3 SD4 SD4 S3~ SC4 ORDER LOG TYPE CLASS FT O0 OOO O0 DHMM O0 220 OHMM O0 120 46 OHMM O0 120 44 MV O0 0!0 Ol GAPI O0 310 O! G~Pi O0 310 O1 IN O0 280 O1 G/C3 O0 350 02 G/C3 O0 356 O1 O0 420 O0 000 O0 PJ' O0 890 O0 O0 358 O1 CPS O0 330 31 CPS O0 330 30 O0 000 O0 O0 000 O0 GAPI O0 310 Ot US/? O0 000 O0 US/F O0 520 80 US/F O0 520 ~0 US/F O0 000 O0 US/F O0 5'30 16 JS O0 000 O0 O0 OOO O0 O0 OOO OD O0 000 O0 G~I O0 310 O1 US/F O0 000 90 US/F O0 520 80 US/F O0 520 BO J'S/F O0 000 00 US/F O0 530 16 US O0 000 O0 O0 000 O0 ,DO 000 OO O0 000 O0 3~i 30 310 O1 US/~ O0 OOO O0 US/F 03 520 $0 US/F O0 520 80 US/F O0 OOO O0 tJS/F O0 530 16 US O0 000 O0 O0 000 O0 O0 000 O0 O0 000 OO 3~Pi O0 310 gl JS/F O0 090 30 US/F O0 520 ~0 JS/F O0 520 80 US/~ O0 OOO 03 NO 0 0 0 0 0 0 0 0 O 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O O 3 4 4 4 4 ,4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 COD 58 63 58 68 5 $ 58 58 6~ 68 68 58 5 B 68 68 $ 8 6,8 58 6 :B 58 ,58 55 58 58 5 B 58 5 8 58 58 58 $8 (DCTAL) 00000000000000 00000000000000 OOO00000000000 00000000000000 OOOO0000000000 00000000000000 O00000DO000000 00000000000000 DOD00000000000 O0000000OO0000 O00000OOOOOO00 00000000000000 O0000000OO0000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O00OO00OOOOOO0 00000000000000 00000000000000 00000000000000 O000000000OO00 00000000000000 00000000000000 00000000000000 00000000000000 OOO00000000000 O00OO000000000 00000000000000 O00000OO00CO00 OOCO00OO000OO0 00000000000000 O000000000OO00 00000000030000 00000000000000 OOOO0000000000 O00000OOOOOOO0 ZV? OlO.MO2 VSRIPIC~TION LISTiN$ PaG~ 6 3TSM SC4 US/~ ]TST SC4 JS O0 ~CE SC4 ASE SC~ O0 &STE SC~ O0 DEPT 11006.5000 SFLd SP -193.5875 GR RHgB 2.4163 ORH3 NPHI 19.A336 PEF QSS 0.0874 BLS LSDT -999,2500 LDTL gIST 0,0000 ACE GR -999,2500 MDT' gTCO -999,2500 DTS~ ASE -999.2500 ASTE LSDT -999,2500 LDTL OTST -999,2500 ACE GR -999,2500 MDT OTC~ -999.2500 QTSM AS~ -999.2500 ~ST~ OEPT 11000.0000 SPLJ SP -188.~375 GR RHOB 2,~065 NPHI 19.~336 PEF QSS 0.0347 QLS LSDT -999.2500 LDTL DTST Z37.0525 ~CE GR -9'99,2500 gTCO -999.2500 OT'S~ ASE -'~99,2500 ASTE LSDT -99~.2500 LDTL DTST -999.2530 GR -999,2500 MOT DTSO -999.2~00 DT'SM ~SE -999.2500 dST: DEPT I0900.0000 SFLJ SP -180.1~75 GR RH93 2.4045 SRH3 NPHI 21.5332 mE= 2SS O.OZ1~ OLS LSST 79.0273 LDT~ gTST 239.0625 ACE GR -999.2500 MDT gTC~ -9'99.2500 STSc1 ~SE -999,2500 ~STE LSDT -999.2500 LOTL 3TST -999.2300 ~CE GR -999.2500 ~DT 5 52 -0 14 -0 -999 35 - 999 -999 -999 -999 -999 -999 -999 -999 5 $2 -0 i1 -0 -999 35 -999 - 999 -999 -999 -999 -999 -999 -999 6 57 -0 I0 -0 78 33 -999 -999 -9~9 -999 -999 -9 ~ 9 530 000 000 000 000 O0 00 O0 O0 9656 8555 0093 81~5 0308 2500 7305 2500 250O 2:500 2500 2'500 2500 2500 2500 9773 8555 0176 0B79 0400 2500 7305 250O 2500 2500 2500 2500 2500 2500 2500 5632 9805 0200 9363 0195 0273 ~555 2500 2500 2500 2500 2500 2500 ILO GR NRAT NCNL GR DTCO ASE LSDT DTST GR OTCO LSDT DTST iLO GR NRAT NCNL GR OTCO ASE LSST DTST GR DTCG LSDT OTST iLO GR NRAT NCNL GR gTC3 ASE LSOT DTST GR gTCO aSE LSDT 1 6B 00000000000000 1 58 00000000000000 t 68 O00OO000000000 1 6~ OOO00000000000 1 68 00000000000000 4.3,579 ILM 7,31.32 153,5625 CALl 5,8325 1,8594 RNR& 1,9649 3273.5000 FCNL 1665.6875 -999.2500 MDT -999.2500 80.0'273 OTSM 139,0625 ~4.2617 ASTE -999.2500 -999.2500 LDTL -999.2500 -999.2500 ACE -999.2500 -999.2500 MDT -999.2500 -999.2500 2TSM -999.2500 -999.2500 ASTE -999.2500 -999.2500 LOTL -999.2500 -999.2500 ~CE -999.2500 4.3289 ILM 4.5515 56.8867 CALI 6.0671 2.0139 RNRA 2.1682 4583.2500 ~CNL 2113.5000 53.4805 MDT 219.1875 78,0273 DTSM 137,0615 42,5742 ASTE -999.1875 -999.2500 LDrL -999,2500 -999.2500 ,&CE -999.2500 -999.2500 MD/ -999.2500 -999.2500 DTSM -999.2500 -999.2500 ASTE -999.2500 -999.2500 LDTL -999,2500 12,9551 'ILM 7,1765 153.5525 C~LZ 5,8210 1,8594 RNRA 1,9649 3273,5000 FCNL 1655,6~75 -999.2500 MDT -999.2500 0,0000 3'TSM 0,0000 44,4180 ASTE -999,2500 -999.2500 LDTL -999.2500 -999.2500 ACE -999,2500 -999,2500 MOT -999.2500 -999,2500 DTSM -999,21500 -99'9,2'500 ~STE -999,,2.500 -999,2500 LDTL -'999,2500 -999,2500 ACE -999,2500 LV? OIO.H02 VERI~ICATIDN L!ST!NS PAGE 7 DTC3 DEPT SP RHOS NPHI QSS LSOT DTST GR DTCO LSDT DTST GR DTCD DEPT SP NPHI QSS LSDT DTST GR DTCD ASE LSDT OTST OTC3 .~SE DEPT SP NPHI QSS LSDT DTST GR DTCO ASE LSDT DTST DTCD SP -99 -99 1080 -i7 2 8 23 -99 -99 -99 -99 -99 -99 -99 -99 1070 -18 2 7 24 -99 -99 -99 -99 -99 -99 - 99 -99 1050 -16 2 7 23 -99 -99 -99 -99 -99 -99 -99 -99 1050 -16 9,2500 DTSM 9,2500 ASTE 0.0000 SFLO 9,9375 GR 2,B928 .DRHD 5,0~88 PEF 0,0156 QLS 0.4023 LDTL 6.0523 AC~ '9,2500 MOT 9,2500 DTS~ 9.2500 ASTE 9,2500 LDTL 9,2500 ACE 9,2500 MDT 9,2500 DTS~ 9,2500. ASTE 0,0000 SFLU 5,4375 GR 2,3713 DRH~ 0,312-5 DEF 0,0132 ~LS 9,1523 LDTL 6,0525 ACE 9,2500 MDT 9,2500 DTSM' 9.2500 ASTE 9,2500 LDTL 9,2500 ACE 9,2500 MOT 9.2500 3TS~ 9.2500 A.ST~ 0.0000 SFLJ 8,a375 GR 2,49.53 ORH3 4,7070 PEF 0 0215 '~ . ~L$ 7,9023 LDTL 4,0525 ~CE 9.2500 MOT 9,2500 DTSq 9.2500 ASTE 9,2500 LDTL 9.2500 MDT 9.2500 DTSq 9.2503 ASTE O.O000 SFLJ 4.4375 GR 2,4690 DRHj -999,2500 DTST -999,2500 5.8093 ILD 55,'i367 GR -0,0068 NR&T 5,6335 NCNL -0,0137 GR 79.9023 DTCD 40.0117 A.S5 -999,2500 LSDT -999,2500 OTS~ -999,2500 GR -999,2500 O'TC3 -999,2500 ASE -999,2500 LSDT -999,2500 OTST -999.2500 30,7236 ILD 43,2617 GR -0,0186 NR~T 7,160'9 NCNL -0,0244 GR 79,4023 DTCO 41.5430 ~SE -999,2500 LSD'T -999.2500 D'TST -999,2500 GR -999,2500 OTCO -999.2500 ASE -999.2500 LSOT -999.2500 DTST -999,2500 11,7520 iLD 70,7773 GR 0,0044 NRAT 5,4734 NCNL -0,0249 GR 78,5273 DTC3 28,3174 ASE -999,2500 LSOT -999.2500 OT$T -999,2500 -999,2500 DTC3 -999.2500 -999,2500 LSCT -999.2500 DTST -999,2500 6.1726 ILD 55.1367 Gq iD .0571 NRAT -999.2500 ACE 3,5237 ZLM 66,3398 CALl 2,2~63 RNRA 4191,2500 FCNL 53 5430 M3T 80.0273 DTS~ ~6.2930 ASTE -999.,2500 LDTL -999,2500 ACE -9'99.2500 MDT -999.2500 'DTS~ -999,2500 ASTE -999,2500 LD~L -999,2500 ~CE 28,31'74 ILM ~2,2B05 CALl 1,932'7 RNRa 4971,2500 FCNL 44.5367 MDT 78,0273 DTSM ~2,91~0 ASTE -999,2500 LDTL -999.2500 ACE -999,2500 MDT -999,2500 DTSM -999.2500 ASTE -999,2500 LOTL -999,2500 aCE 10.2~32 'ILM 69,2148 CALI 2,2307 RNRA 4295,2500 FCNL 67.6523 MDT ~9.0273 DTSM ~3.3242 AST~ -999.2500 LDTL -999.2500 AC5 -999.2500 MOT -999,2500 DTSM -999.2500 ASTE -999.2500 LDTL -999.2500 AC~ 5.7078 iLM 57.7305 C~LZ 2.2~44 RNR~ -9'9'9.2500 ,3.5467 6.0476 2.4182 1731.6875 218.4375 143.0525 -999,1875 -999,2500 -999,2.500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 26.0986 6.0515 2.0334 2443-5000 218.4375 133,0525 -999,1875 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 10.6895 6,1765 2.3206 1849.6875 218.4375 150.0525 -999.1875 -999.2500 -999,2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -99'9.2500 6.3320 7.5046 2.226~ tVP 010..~02 VERIFICATION LiSTiN,3 PAgE NPHI 23,68,t6 PEF 12 QSS 0,0464 QLS -0 LSDT -99'9,2300 LDTL -999 OTST -999.2500 ACE -999 GR 49,9805 MOT 2!9 gTCO 77,0273 DTSM 1413 ASE 44,3242 &.'STE -9'99 LSDT 76,9023 LOTL 77 DTST 245,0525 ACE 37 GR -999,2500 MDT -999 OTCO -999,2500 DTSM -999 ASE -999.,.2500 ~STE -999 OEPT 10400,0000 SFLU 14 SP -163,9375 GR 37 RHSB 2,6409 ORH3 0 NPHI 15.0391 PEF 6 @SS 0.0327 QLS 0 LSDT -999,2500 LDTL .-999 DTST -999,2500 ACE -999 GR -999,2500 MDT -9'99 gTCO -999,2500 DTSM -9'99 AS5 -999,2500 ASTE -999 LSDT 61,5117 LDTL 60 DTST 243,0525 ACE 38 SR -999.2500 MDT -999 9TC~ -999.2500 DTSM -999 ASE -999,2500 ASTE -999 OEPT 10300,0000 SFLU 4 SP -162,6~75 GR 54 RHO5 2,4475 ORHO 0 NPHI 27,1973 PE2 14 ~SS 0.0571 ~LS -0 LSDT -999.2500 LDTL -999 DTST -999.2500 ACE -999 GR -999,2500 MOT -999 gTCO -999.2500 gTSq -999 ~SE -999,2500 aST~ -999 LSDT 80.5273 LDTL 80 DTST 237.0625 AC5 ~0 GR -999,2500 M2T -999 gTCO -999,2500 DTSM -9~9 &S~ -999.2500 ~ST~ -999 DEPT SP NPHI QSS LSDT DTST GR gTCO .4785 NCNL ,0234 ,2500 DTCS ,2500 ,1875 LSDT ,0525 DTST ,1875 GR ,1523 gTCO ,2930 ASE ,2500 LSDT · 2500 D'TST, ,2500 .7051 ILO ,9i80 GR ,0058 NRAT ,3796 NCNL ,0073 GR ,2500 gTCO ,2500 ASE ,2500 LSDT ,2500 DTST .2500 SR ,8~67 DTCS · 07~2 ~SE ,2~00 LSDT .,2500 DTST ,2500 ,2976 ILO ,4492 GR ,0552 NRAT ,6270 NCNL ,0483 GR .2500 gTCO ,2500 &SE .2500 LSDT .2500 OTST ,2500 g~ ,7773 OTCD ,7930 ASE ,2500 LSDT ,2500 DTST ,2500 10200,0000 S~LU -151,5.375 Gq 2.4590 30.22~6 PEF 0.3369 QLS -999.2500 LgTL -999.2500 -999,2500 MgT -999.2500 !37S'4 5,1687 53,2305 GR 0.0:3!i NRAT 12,1113 NCNL -999.2500 DTCg -999.2500 ~S: -999,2500 LSDT -999.~500 .~TST 3669.5000 -999,2500 -999.2500 -999,2500 76,402S 246,0525 47.4492 77,0273 44.41~0 -999,2500 -999,2500 8,6113 40,8.242 1,5948 45'75-2500 -999,2500 -999.2500 -99'9,2500 -999,2500 -999,2500 40.3867 60,0117 -9'99.1875 -999,2500 -999,2500 4,2820 49,8555 2,6553 3863,5000 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 46.6580 78,0273 44,0742 -999,2500 -999.2500 4,2156 50,75!7 2,5292 34B7.5000 -999,2500 -99'9.2500 -999.2500 -999,2500 -999.2530 FCNL MDT DT~i~ · ~ , ASTE LDTL ACE MOT O'TSM ASTE LDTL ILM C A L I RNRA FCNL MOT OTSM ASTE LDT L ACE MDT DTS M AST5 LDTL 4CE ILM CALI RNRA FCNL MOT DTSM AST: LDTL ACE MDT DTSM 4STE LDTL 4C~ ZLM CALI ~NRA FCNL MDT OTSM AST~ LOT' ACE 1646.6875 -999.2500 -999.2500 -999.2500 75.9023 37.2305 215,, 437:5 1~,4.0625 -'999.!~75 -999,2500 -999,2500 8.9707 6,3015 1,52'74 3059,5000 -999,2500 -999,2500 -9991,2.500 -999,2500 -999.2500 21~.4375 111.0273 50.8555 -999.2500 -9'99.2500 4,4031 7,1062 2,5979 1486,6875 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 218.4375 146.0625 -999.1375 -999,2500 -999,2500 4,2429 6.5765 2.8889 1206,6875 -9'99.2500 -999.2500 -999.2500 -999.2500 -999,2500 LVP OiO.HOZ VERIFiCaTION L!$TiN$ PAGE 9 ASE LOOT DTST GR D T C D AS:. DEPT SP RHDB NP~I QSS LSDT DTST GR gTCO ASE LSDT DTST GR gTCO SP RHOB NPHI QSS LSDT DTST GR gTCO LSDT DTST GR OTC~ DSPT SP NP~I ~S.S LOOT 3TOT gTCO LS]T DTST gTCO ASE -999..2300 ASTE 85.1 523 LDTL ;224.05:~5_ AC,~ -999.,2500 MDT -999,2500 OTSM -999,2500 ASTE -999,2500 GR 84,527.3 DTCJ 37,8555 ASE -999,.2~00 LOOT -999,2500 DTST -999,2500 I0100.0000 SFLU -157.4375 Z.3205 DRH2 32.17'T7 0.122~ QLS -999.2500 LDTL -999.2500 AC~ -999,2500 MDT '-999.2500 D'TSM -999.2500 ASTE 86,1523 LDTL 196,0525 -999.2500 MOT -999,2500 DTSM -'999.2500 AST~ 3.0~13 !LO 50,5430 Gq 0.077i NRAT 3.3,85:55 NCNL -0,0991 GR -'999.2500 DTC9 -999,2500 ASE -999,2500 LSDT -999.2500 .DTST -999,2500 GR 86,6~23 gTCO ~!,,1992 AS~ '-999.2500 LSOT -999.2500 gTST -999.2500 10000.0000 SFLU -159.4375 GR 2.4417 DRHO 30.5176 ?~F 0.0757 QLS -999.2500 LDT~ -999.250~ ACE -999.2500 MOT -999,2500 OTS~ -999,2500 AST~ 85.0273 LDTL 221 0625 ~C: 55.7305 MOT 85.0273 DTS~ 34.3!42 AST~ .3,37~2 ILO 51.9180 0,0566 NRAT 14,~395 NCNL -0.0522 -999,2500 gTCO -999.2500 -999.2500 LSDT -9'~9.2500 DTS'T -999,2500 GR 54.2773 gTC] 34.4492 ,~SE 219.1875 LOOT i34.052~ D'TST -999.1~75 9900.0000 -!66.5~75 2.3772 DRHS 26.2595 0.0385 ~LS -999.2500 LDTL -999.2500 -99'9,2500 MOT -999,2500 DTS~ -999,2~00 AST- -~99.2500 LOTL -999,2500 35,5~30 ~OT 82,0273 9TS~I 4!,6580 ~STE 5.3~35 iL3 34.5~30 GR 0.0015 NR~T il.39'26 NCNL -0.0215 JR -9'29.2500 DTC3 -999,25~0 -99'9.2500 LSDT -99'9.2500 DTST -929,25130 GR -9~9.2500 OTC3 -99~,259C A'SE 219.1875 LOCi 150.0625 CTST 57.7930 33.0273 45.3242 -999,2500 -999,2500 2,7 366 50.2930 2,7952 3081,5000 -999,2500 -999,2500 -999,2500 -9'99,2500 -999,2500 56.1055 8,6.0273 41.1680 -999.2500 -999.2500 3.0061 54,5367 2,5936 3193,5000 -999,2500 -99'2,2500 -999.2500 -999..2~00 -999.2500 59.3867 85,0273 3~,4B05 ~4.4023 220.0625 5.2390 40.5~30 2.3459 3611.5000 -999,2500 -999,2500 -99'9.2500 -999.2500 -92'9.2500 -999.2500 - 99'9.2500 -299.2500 S3.5273 243.0625 MD'T DTSM ASTE LOTL ,ACE !LM CALl RNRA FCNL MDT O'TSM ASTE LDTL ,ACE MDT DTSM ASTE LDTL ILM CALi RNR~ FCNL MD T DTSM ~STE LDTL ACE MDT DTSM ASTE LDTL ACE ILM CALi RNR& FCNL DTSM LOTL ~CE MOT DTSM ASTe LC'IL ~C[ 215.4375 157.0625 -999.1875 -999.2500 -999.2500 2.9084 7.2~29 3.04'71 1010.8125 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 218.4375 170,0625 -999.1875 -999,.2500 -999.2500 3,2209 7.4031 2.9065 109.8,6875 -999,2500 -999,2500 -999.2500 -999.2500 -99'9.2500 219. 1875 I~4.0625 -999.1~75 84.0273 3~.2617 5.4332 5,3210 2.~377 1553,687.5 -999.2500 -99'9.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 82.5273 40.98O5 LVP OlO.NO2 VERifICATION LISTING PAG5 10 DEPT RHOB NPHI QSS LSOT 0 T .S T DTCO ASE LSOT OTST DTCO AS E DEPT SP NPHI ~SS LSOT DTST GR DTC'D &SE LSDT OTST DTC 0 SP RHO~ NPHI ~SS LSDT DTST SR OTSO &SE LSDT DTST r-, oR DTCS ~SE DEPT SP NPHI ~SS 9300.0000 SFLd -15'7,9375 GR 2,4512 DRHO 29,8828 PEF 0,0571 QLS -999.2500 LDTL -999,2500 ACE -999.2500 MDT -999.2500 DTSM -999.2500 ASTE -999.2500 LOTL -999.2500 ACE 57.6367 MDT 86.0273 DTS~ 41,1055 ASTE 9700.0000 SFLU -161.3125 GR 2.4143 DRHJ 27.6855 PEF 0,0244 ~LS -999.2500 LDTL -999,2500 ACE -999,2500 MDT -999o2500 DTSM -999.2500 ASTE -999.2500 LCTL -999,2500 ACE 46.1367 MDT 86.0273 OTSM 33.5117 ASTE 9600.0000 SFLU -185.6875 GR 2.4280 DRHO 26.2207 m~F 0o0146 QLS -999.2500 LOTL -999.2500 ACE -999.2500 MDT -999.2500 DTSM -999.2500 ASTE -999.2500 LDTL -999,2500 AC~ 43,59'92 ~aDT 84.0273 DTS~ 35.7617 AST~ 9500.0000 SFLJ -159.4375 GR 2.4~75 DRqS 29.7852 PS~ 0.0752 QLS 3,5549 ILO 65.1523 GR 0,0552 NRAT 8,1113 NCNL -0.0332 GR -999.2500 DTCO -999.2500 ASE -999,2500 LSDT -999.2500 DTST -999.2500 GR -999.2500 DTCD -999.2500 A,SE 218.4375 LSDT 167.0625 OTST -999.1875 3.5627 ILO 50.3242 GR O.O010 NRAT 3.488,5 NCNL -0.0059 GR -999.2500 DTCO -999.2500 ASE -999.2500 LSDT -999.2500 D/ST -999.2500 GR -999.2500 DTCD -999,2500 ASE 219,1875 LSDT 1~9,052~ DTST 44.9180 5.1257 ILO 48.5!17 GR -0.0098 NRAT 6.2937 NCNL -0.0135 GR -999.2500 DTCO -999.2500 ASE -999.2500 LSDT -999,£500 DTST -999,2500 -999.2500 DTCC -999.2500 219,1575 LSaT 151.0~25 CTST -999.1B75 3.5803 iLD 63.0117 GR 0.0571 NR.~T 7.9578 NCNL -0.0439 GR 3.2405 53.1580 2.6057 3159.5000 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2'500 86.0273 243,0525 4,1~53 50,5i!7 2,4592 3857,5000 -999',2500 -999,2500 -999.2500 -999.2500 -99'9,2500 -999.2500 -999,2500 -999.2500 87.0273 243.0625 6.4595 44.0~30 2.3362 3697.5000 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 80.4023 231.0625 3.5120 64.7773 2.6819 5699.50D0 -999.2500 ILM CALl RNR~ FCNL MDT 3TSM ASTE LDTL ACE MDT DTSM ASTE LDTL ACE ILM CALl RNRA FCNL MDT DTSM ASTE LOTL MDT OTSM ASTE LDTL bCE ILM CALI RNR~ FCNL MDT D'TSM ~STE LDTL MDT DTSM AST= LDTL $CE iLM C~LI RNR~ ~CNL MDT 3,3518 6,6414 2,7268 1158,5875 -999,2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 '-999,2500 86,6523 40.4180 3.9905 8,6414 2.5393 1518,6.8'75 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 87.2773 38,7305 6.3210 6,2546 2,4124 1532,6875 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2590 -999.2500 79.0273 36.5742 3.5061 7.9695 2.8616 1292,$$75 -999.2500 LVP OlO.HO2 VERIFICATION LISTiNS PAG5 11 LSDT OTST GR OTCO LSDT OTST DTCO asE DEPT S ? RHDB NPHI QSS LSDT OTST OTCD LSOT OTST DTCD DEPT SP NPHI ,FDSS LSOT DTST GR OTCO aS E LSDT DTST GR OTCO aSE D~ZPT SP NPHI ,QSS LSDT DTST GR OTC3 LSJT -999,2500 LDTL -999.2500 ACE -999,2500 MDT -999,2500 DTSM -999.2500 AST~ -999.2500 LDTL -999,2500 AC5 61.8555 MOT 82,0273 DTSM 4!,6055 ASTE 9400.0000 SFLJ -162.6875 GR 2.3245 ORHO 30.7129 PEF 0.0305 QLS -999.2500 LDTL -99'9,2500 ~.CE -999,2500 MDT -999.2500 OTSM -99'9,2502 ASTE -999.2500 LDTL -999.2500 ACE 45,.7517 MDT 8'9,0273 OTSM -999.1575 AST~ 9300.0000 SFLJ -155,9375 GR 2.5022 DRHD 25.0000 PEF 0,0273 ~LS -999,2500 LDTL -999,~500 ,aCF_ -999.2500 MOT -999.Z~00 DTSM -999.2500 AST~ -999.2~00 LDTL -999,2500 aCE ~9.2305 MDT 8~,0273 DTSM 39.3555 ~ST~ 9200.0000 SmLJ -169.5875 GR 2.4260 DRH3 31.2983 PE~ 0.0B74 QLS -999.2500 LDTL -999.2500 ACE -999.2500 MDT -'999.2500 9TSq -999.250C AST~ -999.2500 LOTL -999,2500 OTC2 -999,2500 ASE -999,2500 LSDT -999.2500 D'TST -999.2500 GR -999.21500 DTCO -999.2500 218.~375 LSDT 134.0625 DTST -999.1875 2,9202 ILD ~.5.!055 GR -0,0005 NR~T 4,5882 NCNL 0.0049 GR -999,2500 DTCD -999.2:500 AS5 -999,2500 LSOT -999,2500 OTST -999,2500 GR -999,2500 DTC~ -9'99,2500 A:SE 219.1875 LSDT 154.0625 OTST -999.1875 4,9226 ILD 56,1992 GR 0.0220 NR&T 5,2039 NCNL -0,,0400 GR -999.2500 OTCD -999.2500 ASE -999,2500 LSDT -999,2500 DTST -99'9.2500 SR -999.2500 DTC~ -999.2500 ASE 218.4375 LSDT 179.0625 DTST -999.1875 4.5713 !LO 65,9548 GR 0.0503 NRaT 9,2832 NCNL -0,0669 GR -999.2500 DTCS -999.2500 &SE -999.2500 LSDT -9'99,2500 OTST -999.2500 GR -'999.2500 DTC2 -999,2500 -99'9.2:500 -999.2,500 -999,2500 -999,2500 -999.2500 -999.2500 84.5273 211.0625 2,9260 2,6780 3571,5000 -999,2500 -999,.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 92.4023 245,0625 5,9929 52,7305 2,3420 3337,5000 -999,2500 -999.2500 -999,2500 -999,2500 -'999.2500 -999.2500 -999.2500 -999.2500 79,1523 191.0525 4.7976 61.4180 2.7971 2997.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DT'SM ASTE LOTL ACE MDT DT.SM ,ASTE LOTL ACE ILM CALI RNRA FCNL MDT DTSM ASTE L~TL ACE MDT D'TSM ASTE LOTL ~CE ILM CALI RNRA FCNL MDT ASTE LDTL ACE MDT DTSM aSTE LDTL ACE iLM CALI RNRA FCNL MOT DTSM AST~ LDTL ACE MDT OTSM -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 $6,4023 37.7617 3.0100 6.9,421 2.5323 1250.5875 -999.2500 -999,2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999,2500 -999.2500 90.5273 ~0,0742 5,4851 7.7000 2.51,39 1327.6875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 79.2773 41.0117 4.7976 ~.1270 2.951~ 1015.3125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP 010.,H02 VERIFIC&TIDN LISTING PAGE 12 DTST gTCO SEPT SP RHDB NPHI 2SS LSDT DTST GR DTCD ASE LSDT. DTST GR OTCg SEPT SP RH3B NPHI QSS LSDT DTST GR gTCO ASE LSDT DTST gTCO ASE CEPT SP NPHI QSS LSST DTST GR AS_= LSDT OTST SR OTCD ~SE -999, 2500 ACE 59,2930 MDT 87.0273 OTS~I 9100.0000 SFLU -1,4!,1875 GR 1,8380 52,0505 PEF 0,0049 ~LS -999,2500 LOTL -999,2500 ,ACE -999.2500 MDT -999.2500 DTSM -999.~500 AST~ -999,2500 L~TL -999.2500 ACE ~2.2930 93.0273 DTSM 42.4805 ~,ST~ 9000.0000 SFLU -185,1875 GR -999.2500 ORH3 -999,Z500 PEF -99'9.2'500 QLS -999.2500 LDTL -999,2500 ACE -999.2500 MDT -999.2500 DTS~ -999.2500 ASTE -999,2500 LDTL -999.2500 ACE 39.1992 MDT 55.0117 DTS~ -99'9.1875 ASTE 8900.0000 SFLU -157.6875 GR -999.2500 ORW3 -999.2500 PEF -9'99.2500 QLS -999.2500 LDTL -999,2500 ACE -999.2500 MDT -999.2500 DTSM -999.2500 AST~ -999.2500 LgTL -99'9.2500 ~C~ -999.2500 MOT -999.2500 DTSM -999.2500 AST: -999.2500 ASE 219.1875 LSDT 168.0525 DTST -999,1875 2,~342 iLS 40,7617 GR -0,0308 NRAT 11,1270 NCNL -0,023.4 GR -999,2500 gTC3 -999,2500 -999,2500 LSDT -999.2500 DTST -999,2500 GR -999,2500 gTCO -999,2500 ASE 213.~3'75 LSDT I~5.0625 OTST 41.7305 2000.6875 ILO .34.4492 GR -999.2500 NRAT -999.2500 NCNL -999.2500 GR -999,2500 gTCO -999,2500 ASE -999.2500 LSDT -999.2500 DTST -999,2500 GR -999.2500 OTC,] -9'9'9.2500 ASE 219.1875 LSDT 110,0273 9TST 33.5580 2000.5875 36.2930 GR -999.2500 NR~T -999.2500 NCNL -999.2500 GR -999.2500 DTCS -999,2500 -999.2500 LSDT -9~9.2500 DTST -999.2500 G~ -999.2500 ~TCS -999.2500 -999.2500 LSOT -9'99.2500 gIST -999.2500 -999,2500 68,0273 i93,0525 2.4241 38.9180 3.9495 1763.6875 -999.2500 -999,2500 -99'9.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 93.0273 204.0625 67.5898 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2~00 -999,2500 -999.2500 -999.2500 -999.2500 15,5270 205.0525 2000,6875 -'999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 A S 'T E LOTL ACE ILM CALI RNRA FCNL MDT DT.SM AS'TE LDTL ACE MO'T OT.SM AST~ LDTL AC~E !LM CALI RN~A FCNL MDT DTSM ASTE LDTL ACE MDT DTSM ASTE LDTL ~C~ ILM CALI RNR& ;CNL MDT DTSM ASTE LDTL ACE ~DT DTSM ~STE LDTL ACE -999.2500 88,4023 41,94'92 1.9307 8.1035 3.8928 452.8906 -99'9.2,500 -999,2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 92.2773 40.1992 2000.58'75 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -9'99,2500 -999.2500 -999.2500 -999.2500 57,0117 ~.2305 64.27'13 -99'9,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 ']EPT BBO0.O000 SFLJ 2C00.6375 ILD 42.6992 ILM 2000.6:575 LV? OlO.HO2 V~RIFIC~T,iON LiSTIN~ PAGE 13 SP -211 6~75 GR . k,x' ~HOB -999,2500 DRHg NPHI -999..ZSO0 ~EF QSS -'999.2500 QLS LSDT -999,2500 LDTL C'TST -999.2500 ~C6 GR -999.2500 MDT OTCO -999.2500 OTSM ASE -999.2500 ASTE LSDT -999.2500 LOTL OTST -999.2500 ACE GR -999.2500 MDT gTCO -999.2500 DTSM ASE -999.2500 ASTE OEPT 8700.0000 SFLU SP -215.43'75 GR RHOB -999.2500 ORMO NPHI -99'9.2500 PE~ QSS -999.2500 QLS LSDT -999.2500 LDTL DTST -999,2500 ACE GR -999.2500 MDT DTCg -999.2500 DTSM 4SE -999.2500 ASTE LSOT -999.2500 LDTL OTST -999,2500 ACE GR -999,2500 MDT DTCO -999,2500 OTSM ASE -999.2500 ASTE OEPT 8595.5000 SFLU SP -215.9375 GR RMOE -999.2500 DRH3 NPHi -999,2500 oEF ~SS -99'9.2500 QLS LSDT -999.2500 LDTL DTST -999.2500 ACE SR -999.2500 MDT OTCD -999.2500 OTSM ASE -999.2500 .~ST~ LSDT -999.2500 LDTL DTST -999.2500 ACE SR -999.2500 MDT OTC] -999,2500 OTS~ ,~SE -999.2500 AST= 32.9805 GR -999.2:500 NRAT -999.2500 NCNL -999,2500 GR -999.2500 gTCO -9 '99 . Z 500 .& S E -999. 2500 L.SDT '-- 9 I~ 9 . 2 .500 C' T S T -999,2500 GR -999.2500 DTCO -999.~500 -999.2500 LSDT -999,Z500 DTST -999,2500 2000.5575 ILO ~1..3857 GR -999.,2500 NRAT -99'9.2500 NC~L -999.2500 GR -999.2500 gTCO -999.2500 ASE -999.2500 LSDT -9~9,2500 DTST '-91}9,2500 GR -999.2500 DTC] -999.2500 4SE -999.2500 LSDT -999.2500 DTST -999.2500 2000.5875 iLO 34.0430 GR -999.2500 NR4T -999.2500 NCNL -999.2500 GR -999.2500 gTCO -999.2500 ASE -999.2500 LSDT -999.2500 DTST -999,2500 GR -999,2500 DTC9 -999.2500 ~SE -999.2500 LSDT -999.2500 DTST -999,2500 ~:::: FILE TRAILER ~:~: FiLE NAME :EDIT .JO1 SERVICE NAME : V:RSI~N ~ : DATE : MAXIMUM LENGTH : 1024 -999.2500 -999.2500 -999.25O0 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999~2500 -999,2500 -999.2500 -999,2500 177.9375 -999,2500 -999,2500 -999,2500 -~9.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 143.9375 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 CALi RNRA FCNL MOT gTSM ASTE LDTL ACE MDT OTS:~ ASTE LDTL ACE ILM CALI RNR6 FCNL M D'T OTSM ASTE LDTL ACE MDT O T S ~ ASTE LDTL ACE ILM CALi RNRA FCNL MDT OTSM ASTE LOTL ACE MDT OTSM ASTE LDTL. ACE -999,2500 -999,2500 -99'9,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 2000.6875 -999,2500 -999,2500 -999,2500 .-999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2000.68'75 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -9'99.2500 -999,2500 LVP OIO.MO2 V'E~!~IC~Tt!ON LISTINS OAGE 14 WILE TYPE : NEXT FILE NAME : ~:~-~, TAPE TRAILER SERVICE NAME :EO'IT OATE :85/1Z/18 ORIGIN TAPE NAME :1057 CONTINUATION ~ :01 NEXT TAPE NAME : COMMENTS :SCHLUmBERgER NELL SERVICES PROPRIET,&R¥' FIE:LO TAPE ~;~ REEL TR~ILER N~::~ SERVICE NAME :EDIT D~TE :8~/12/18 ORIGIN : REEL NAME :1497411 CONTINUaTiON ~ NEXT REEL N,~ME : COMMENTS :SCHLUMBERGER WELL S~RVICES PROPRIETARY FIELD TAmE PAGE 1 *************************************** * DATA [)ISCRiMiNATIO~{ , , * I~E~I~ILITI CO{,'~PA;~¥ : ~,,~:VkL~a liSA ii,:C ~',~<t,~ .... : $C0 21~ 16 PAGE 2 * *10100 *lOlO1 *10102 ~1010.3 *100 '16.7 *10104 *100 '13,9 *10105 *100 ,15,1 *10106 *100 '15.2 *10107 *100 *1010~ *10109 *100 .14.3 *1011~ ,100 ,1.4,7 *lOlll *100 '14.7 *iOl12 *100 *10114 .100 .10.9 tOilS *100 ~ ~, 101 *10123 *100 .17,2 * 10124 *10127 *100 *: I 0128 *10129 .10'0 .17~7 ,101 ~' * 99 ,18,0 *10133 ', 00- *10134 *10135 *lO0 '16.6 *10137 * 100 * 1 a ' 6 :'I0138 * 99 ,1,9,3 *10139 * 99 ,17'5 :*10140 *100 .12,9 , , * 97.0 * 13,0 * 96,6 * 13.6 * 96,6 * 13.b * 96.4 ~ 13.6 * .~ * '* 96.3 * 13.6 * 96.1 * 13.6 * ,52 * 96.0 * 13.b * 95.8 * ~3.6 * 2.96 * 95,6 * 13.~ * 95.5 * 13,6 * 95,,~ * 13.6 * 95.2 * 13.6 * ,6:1 * 95,1 * 13,~ * 94.9 * 13,6 ~ 47 * 94,~ * 13,6 * 94.7 * 13;6 * 94,,0 * 13,6 * 94.4 ~ 13,6 * 4 58 * 94,2 * 1.3,b * 94.0 * 13,6 * 30 93 * 93. t)J * 13,6 * 93'6 * 13,6 * * 93,4 * 13,6 * 9~,2 * 13,6 * 2.25 * 93 · 1 * I .3,0 * 92,9 * 13,6 * 92,5 * I '6 * 56 * 92,4 * 13,6 * 2'40 * 92,2 * 13,6 , 92.0 , !3.b , 5'15 * 91,~ * 13'6 * ~' 91 '6 * 13,5 * 91,5 * 13,5 * 91,2 * 13,5 * 90'8 * ..3,5 .* a,77 * 90,6 * l::~ 5 * 90,4 * 1,- :5 * 90.3 * 13,5 * , , , , * 90 * * 3:38 , , 2.94 * , .68 * * .16 * , ,b2 * , ,59 * , 2,96 * * .86 * * ,37 * * ,60 * * ,61 ~ ,45 * * ,47 * * ,03 * * ,01 * 3,51 * * 4,52 * , 5,97 * * 27,19 * * 21,09 * * 5,79 * * 2'45 * o.~ ~:25, 0 * 60* * 31 * 0 , ~:56 , * 45 , * 3;68 * , :oo , * , 42 * * ,99 * , 1 .:28 , ~ 2 74 * 0 * 320* 0 ~ 872* . 1303. , 401 * 0 * 32* , 29, 29, 29. 29, 29, 29, 29, 29. 29, 29, 29, 29, 29, 9, ~9, 29, 2g. 29, 29" 29, 29, 29, 29, 29' 29; 29; 29 ,: 29, 29, , 483, *2 482, *2 478, *2 475, *2 475, :22 475, 474 473 ~67 466 5 * ,5c~ * 0 * 0 * :*i0142 *i()0 *1 8 * * 90,1 * 13'5 * i6 11 * 0 * () ~ 1.6,09 * 29, · 10143 *i00 '1 ::1 * * ~9,9 * 13, , . · 99 *19.5 * * ~9'7 · i3.5 * l~,vI * 0 * 0 * 1~,40 * 29, ~ · lOl,,lS *100 *~6.3 * * 8~'5 * 13;~ * 2.2n * 0 ~ 0 *z.20 * 29 · ************************************ *******~********* ************************* 344, 33.1 322 ' , 64 · 64 * 64 · 64 * 64 * 64 * 64 * 6,5 * 6"/ * 67 * 67 * 69 * 65 * 64 · 64 * 64 COMPANY : Ci. iE:vh'ON OSA I;~C WELh : SCU-215-.Ib PAG~2 3 *********************************************~*********************************************************** * SAT. *EFF, *2Nh * EFF, * ~C-F'f *,i~-~']~I~'~ * GAS ~ ()ih * ~ATER * PERM. * PERM. * PER~. 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GRAIN , , · , , , · , , , , · , * 73.2 * 12.6 * 73.0 * 12.6 , * 72,6 , 12.6 * 72.5 * 1.2.6 * 72.4 * 12'6 * '72,0 , 12,6 .77 * , .07 * ,O2 * . .19 * * 71,9 * 12,6 * ,71 * 71.7 * 17.~ · 1.50 , '~ 71,6 * 12,6 * 71.4 ~ 12.6 * 1.09 * 71,3 * 12,6 * 71,1 * 12.6 * 71.0 * 12,6 * 70,8 * 1~.6 * * 70,7 * 1~,6 * 70.5 * 12.6 * .06 , , , * 70.3 * 12.6 * ,06 * 70.2 * 12'~ * .~9 * * 70,0 * 1~,6 * 69.8 * 12,6 * 69~7 * ,'1~;6 *', 5.69 * 69.5 * 12.6 * 59,3 * I2'6 * 3.14 $ 69,0 * 12~6 * 1,57 * * 68.7 * 12,6 * ,03 ~' 68,6 * I 2,6 * * , * * t2.6 * ,55 * 68.2 * 1.2.6 * 1'86 * 68.1 * 12'6 * ,42 * 67,6 * 1~,6 * 67'3 * 12~6 .02 * o * 0 * 0 * 0 * 0 * o * 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 * , 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 0 * 0 * 0 * 0 * 0 * 0 * .01 * .08 * 196, ,2,54 o * .08 * 196, , , ,. ., 0 * .01 * 196. *2,64 0 * .07 * 196,*2,6~ 0 * .02 * 196, ~2,64 , , , .- 0 * ,19 * * .71 , 1,50 , .85 * 1,08 * 1.10 * ,63 * 1.25 * 3,33 * .60 * .06 , * .06 * .69 * 3,40 0 , ~ O1 * 0 , 4 ,01 * 12 0 , 0 , 0 * 1 0 , 2 0 , 0 , , 80 * 73 * I4 * 98 * 57 * :70 * 03 * 05 * 0 * .55 0 * 1.86 0 * ,42 0 * 1,17 0 * 5,68 0 * 3'20 · *,76 28, 28, * * 28, * 28, * 28. 28. 28, 28. * 28 2@ * 28 2~ * 2~, 28, * 28, * * 28 * 21 * 28 * 28 28~ 28, 28, 28, * 28, * 28, 1, * 1, * 1, * 1, * 1, * 1, * 1,,* I, * I, * i, * I, * 1.. * 1, '* 1, * 1 ! 1 * 1 ! ! 1, * , !, *10279 , 70 ,17.5 *10280 *100 ,13.0 * * * *10283 *100 *12.0 *'10284 *100 ,13,2 *10285 *100 ,12.4 , · *10288 *100 .13.7 0289 *lOt) .15 1 ~0290 *lO0 .15:7 *10291 *100 *15,0 *10292 *lOO *15,3 0293 *100 ,15,0 ~0294 *1.00 ,1.4,3 ~10295 *100 *15,5 *10296 *lO0 .'16,6 *10298 .1100 ~ ,4 , , , *I0300 *100 '1,2 5 ,100 ,14 8 *10302 *100 'i6 5 gl 0304 * 96 '17 6 0305 * 95 ,18 .8 , , oo *1030~O0 *i5.4 :~ :0309 *100 * 6 1 , oo 9 : oo , *10314 *100 '15.7 * 03:I5 *t00 '14'9 03116 *100 ,14. ::*;10317 * O0 *1~.:6 .10318 *10o .16,0 0:31:9 '* 99 ,' ~' · 10320 , 95 *17.6 · 10321 * 98 *I6,9 · 10322 *100 ,15,2 * * 67.1 * 12.6 *: 5.59 * 0 * 0 * 5,11 * 28, * 1:,.: * * 67.~0 , 12'6 * 1,89 * 0 * 0 , 1.B9 * 28. * 1" * 324 i00 ,15~ * * 6G.7 * J. 2.G * 1.95 * o :, 0 * 1,95 * ~ * , * ::*10325 *100 ,i4.2 * * ~6.5 * I" 6 , ..4~ * ~ * 0 ,* ,45 ;* 28~ * 1. * ************************ ********************************************* 196, *2 196, *2 194. *2 193, '2 192, 190. ~ 189' ls9, 187' 2 184, ~ 169, 159, 52' ,152, 15 !, 14:9' 135, 128, 124; 12I ~ i2o, SAT. *E~F. *2NO * EFF. * HC-FI': ~l~,~7~g.,I.~ * G,~,~ * 'OIL * ,A',C~ * PERM. * PERM, ~ PERM GRAIN * , , , 110327 *lOO ,12,3 110328 * 99 ,1.2.6 *10329 * Bt; *ll e8 *10330 * 70 ,16.3 *1,0332 * 79 .16,8 ~10333 * 80 *lb,4 *10334 *10(~ .14,1 * , , , *10336 *100 .11.3 * *10337 q 78 .15,8 *10338 * 83 .15 3 10340 , 81 ,18 2 * :10341 *86 ,148' 0342 * E5 *14 1 * 0 46 * 67 '17,6 0348 * 78 * .1 *10349 * 74 *1~ 7 * *10350 * 70 ,17 7 * ,10351 * 69 ,17 8 * 352 ~ 68 116 8 * 354 * 77 .13 ~g355 * 87 '12 *10361 * 78 *lb,5 *10363 ~ 91 .16,2 * 365 * 90 ,17,2 * *.10366 * 76 *I]~,1 * *10367 * 84 * ,1 * 0368 * 98 ,15,6 ~0369 *1()0 816.4 371 *1oo 8 *10372 *lOO *14 ~ * *10)7] *I00 ,1.3 7 $10374 *100 * 9 b , ,~ , * 66.2 * 12.t~ * 6o.1 * I2.b * ,10 * 66.0 * 65.0 * 1..2.5 * 2,38 * 65,7 * 12.5 * 5.bb * 65,5 * 12.4 * 3,3~ * 65.4 * 65,2 * 12.4 * 1.13 , , · * 65,(~ * 12,4 * .04 * 64.0 * 12,4 * 2.35 * 64,7 * 12.3 * 1,39 * 64,6 * 12,3 * 1,98 * 64,4 * 12,3 * 12.77 * b4,2 * 12,3 * ,U?,, * 64.1 * 12.2 ~/: ,4,.. * 63.9 * 63.7 * 12.2 * b3.6 * 12 I * 3.02 * 63.4 * 1.2:1 * 63,2 * 12,0 *' 2,11, * 63,..l * 12.0 * 62,9 * 12,0 * ,01 * 62..q * t~2,6 * 1I 9 * 62.4 * 11 * 62,2 * 62.1 * 11 7 * 61.9 * 6:1.8 * 11.7 ·'38 * 6'1.7 * 11,6 $ 1.69 * 61,5 * 61.3 * 1. l,5 * 61.2 * 11 5 * 2.85 * 61, .0 * i3. * 60,.9 * 11 * 60.7 * 11 * 60,5 * 11 * 60.4. * * 60,2 , I! 5 * * 60,1 * 1 * 59,9 * 11 5 * 5g.'~ * * 59.'7 * I1 5 * 5 * 3 5 * 3 5 * 1 5 * 2 5* 836* 62 * .4.9 * 19 * b3 * ,27 * .28 .57 ,30 * 0 * 0 * ,10 * 0 * 0 * .15 * 0 * 0 * ,01 ,Og * 0 * ,37 * .13 * O , 1.48 * .05 * O * 1,12 * .03 * 0 * ,84 0 * 0 * 1.11 * 0 * 0 , ,04 * .04 * 0 * ,68 * ,0~. * O * .55 n , ,01 , 1,25 .1,4 * 0 * 5,28 0 * 0 * ,37 0 * f) * .15 ,10 * 0 * ,9B ,05 * 0 · .09 * 10 * 0 · ,57 * '29 * ,01 * ,91 '.07 * 0 , ,38 .07 * 0 * 1,03 * ,15 * 0 * 1.21 * .43 * .01 * 1,99 * ,53 * .01 * 2,07 * .31 * .Ol * ,.96 * · 17 * 0 * ,50 .01 * 0 , .10 0 * u * .02 * 0 *' .04 .02 * o · ,47 * .01 * 0 * .46 * 0 * 0 * 1,67 0 * o , 2,7a * .02 * o * 5,26 * ,07 * 0 · 97 * .02 * 0 * I 55 0 * 0 * 1 og * 0 * 0 * 257* 0 * 0 * ,27 0 · 0 * ,2fl * 0 * O r ,57 * 0 * 0 * .30 0 * 0 * ,01 28, 28, 28, 28, 28, 28. 28, * 28, * 28, 28, * 28, 2B, * 27, 27, * 27. * 27, * 27 27 27 27 27 27 25 25 2.5 , 25 , 25, * 25, 25;, 25, 25. 25. * 2 5, 25, 25. * 25. 119 117 1,: 114, : 113, 113, : ilo. 104; : 104, * 88 ' , : 79; '9, 1, COMPANy : CHE¥.RON USA 1NC WELL ." SCU-2iM...IO PAGE 7 ********************************************************************************************************* *DEPTH WAT. *POR, P[)R, * CUb. * CUM. * PER~. * PEf<.~. * PgRa. * PERM, * CU~, * CU~. * CU~. * SAT. *EFF, '2,~[) * EFF. * ~C-F'r *i~;~l'Rl~:~ * GAS * OIb * ~A]'ER ~ PERM. * PERM, * PERM. *10376 * 99 .14.6 '1037')' * 73 '17 3 *10378 * 91 ,15:7 *10379 * qb ,15.4 *10380 * 79 ,14.6 '1038.1, * ~8 ,14,3 *10382 * 95 ,15.8 *10383 '103~4 *~0385 * *10386 * 10387 * 95 *10388 *10389 10391 *10392 *10393 ,100 ,12.7 ~10394 *100 *10395 ,100 '11.7 :~0396 *100 ,11:7 * 0397 *10401 *1.00 ,12.2 I0402 * 99 *13,1 10403 * 99 :10404 ,100 *1~,0 0405 *100 10406 *'10408 *100 *10409 .100 *10411 , 93 :I041~ * 99 04 ,10o *i. 0414 *100 *1o415 ,100 ,12 5 * 59,5 * 11.5 · 1.19 * 59.3 * 11.4 * 59.2 * 11.4 * 59.0 * 11.4 * 5B,9 , 11,4 * 58.7 , 1!,3 * 5a.6 , 11,3 * 58.3 * 11,3 * 5~.1 * 11.3 * 1,05 * 57.9 * 11,3 * ,49 * 57,8 * 11.3 * .54 * 57.7 * 11.3 * 57.5 * 11,2 * 57.4 * 11,2 * 57.2 * 11,2 * 57,1 * 1~,2 ; 1.9b * 56.9 $ 11.2 * * 56.8 * 11,2 * 5b,6 * 11,2 * 56.4 * 11.2 * 56.0 * 11.2 * 55.9 * 11.2 * ~5,7 * 11,2 * 55.5 * 11.2 '* 55.3 ; I1,~ * ,21 * 55.2 * 11, .2 * .10 * 55,1 * 11.2 * 54.9 * 11.2 , .42 * 54,8 * 1 I, 2 * 54..6 * 11.2 * 54.5 * 1'1,2 $ ,0~ * 54,,~ * 11.2 * 54.3 * 11,2 0 * 1.11 0 * .96 ,01 * .81 O * 1.17 0 * .09 0 * ,14 * 0 * 1.04 0 * 1.15 .52 * .30 .40 ,35 * .18 * 3.2 * ,9C) · 0 * 1.44 25, 25, 25, * 25, * 25. 25, 5, 25, * 25, * 25, * 25, * 25. * 25, 25, 25, 25, 25, 25,, 25° * 25. 2 b,, 25 ** 25, 25, * 25, 25, 25, * 25, * ,2,5, 25, 25, 78 77 76 75 75 75 74 73 71 71 70 70 70. b9 '2,74 67.68,, 67, ~2 7 65 ~2,75 65 ~; 75 . 266* 6 ~2 67, 66 *, 61 ~ *. 54.0 *10428 * 6{~ .14 . * * 535fi USA lt',,,C ,,,!EL, L, : SC.!,,.!-215-1b P~GE 8 ~DKPT~ ~'A'r, ~PmR. F'OR. * C~S:,, · CL,I~,. , PER+~, · P~t,,1. ~ P~Ri.l. · PERM. ~ CU~, · CUM. * CU~ C~EAN · *10429 * 62 10430 * 53 T13.3 *10431 * 54 ,13.7*10432 * 59 *13.4 10433 * 51 ,12.8 10434 * 49 *10435 * 51 ,13.5*10436 * 4.9 *lq.(.', * 0437 * 45 ,15,5 *10438 , 42 .16.3 04,t0 * 35 0442 * 36 *.10443 * 38 *10444 * 40 *t4 4 I0445 * 39 ' 0446 * 45 *1 04:48 * 44 *10449* 40 *10450 * 40 .14.9 0452 , 66 .1o,2 10459 * 54 *10460 * 43 '14 'i046] * 41 '14 6 *'10462 * 4.4 ~10463 , 46 .14 9 :10464 * 4~ :16.3 *~0474 .10o *10480 ,l()o *11.() *10481, ,100 ,10482 *100 *i} 7 *,10483 .100 10485 *100 10487 ,100 *I1.i ,1(i491 .1ilo .11.5 * 53.4 * 11.0 * 53.3 * 10,9 * 53.2 * 10,9 * 53.0 * lO,g * 52.g * 10.8 * 52.8 * 10.7 * 52.b * 10,6 ~ 52.5 * 10,6 * 52.4 * lO,b * 52,2 * 10,4 * ,03 * , 08 * ,10 * ,07 ,09 ,11 .15 . lg ,45 .* .77 * 52.0 * 10.3 * 1,24 * 51.9 * 10,2 * 1,08 * 51.1 * 10 1 ~ 51.6 * It'.,:O * ,64 * 51,.4 * 9,9 * .48 * 51.3 * 9,8 * * 51,1 * 9,7 * 51,0 * 9,7 * 50,8 * 9,6 * 50.7 * q.5 *' ,37 ~ 50,6 ; 9 ~ '* 50.4 * 9:3 * 50,3 * 9 2 ~ 50.1 * 9'2. * .02 * 49.6 * 9.1 * 49,5 * 9,0 * * 49.3 · 8,9 * 49.2 * 8,8 * ,36 * 49.0 * 8,~ * 48,q * B,7 * 48.~'1 * 8.7 ~. .01 * ,* 48.2 $ 8.7 * 47 g. * 9.7 ~ 47.8 * 8,7 * 47.7 · ~{~7 ~ 47,6 · 8,7 * .0.~ * 47,4 * ~.7 * ,01 * * 46,9 * ~.7 0 * 0 · 0 * ,01 * 0 * 0 * ,0].. * 0 * 0 * ,01 * 0 * 0 * .01 * 0 * 0 * ,01 * 0 , 0 * .01 * 0 , 0 * .02 * 0 * 0 * ,07 * .Or * 0 .1.4 * ,01 * 0 * ,24 * ,02 * 0 * .20 * .02 * 0 * ,16 * ,02 * 0 * ,10 * .02 * 0 * .07 * ,01 * 0 * '06 * .01 * O * ,03 * ,01 * 0 * ,04 * ,01 * 0 * .03 * 0 * 0 * ,06 * .Ol · 0 * .08 * .01 * 0 * .12 * ,01 , 0 * ,(}9 , 0 * 0 * o w 0 * 0 * · , 0 * 0 * 0 * ,05 * .ol * 0 · .05 * . Ol * 0 * .04 * ,'01 * 0 * .Ob * .01 * 0 * .21 * ,ul * 0 * · , 0 * 0 * 0 * 0 * .01 * · , 0 * 0 * , Ol o , 0 * .04 0 * 0 * 02* 0 · 0 · Ol * 0 * 0 * 02* 0 * 0 * 03* · , , 0 * O * ,01 * · , 0 * 0 * .02 * 25, 25, 25, 25, 25, 25, 25, 25, 25, 25, 25. 24, * 24, 24, * 24. 24, 24, * 24, 24, 2~, *' 24 *' 24 23 23, * 23, * 23, , 23' 23, 23, * 23, * 23, * 23, * , 23, 23~ * 65, 64, 64, 64, 64 64 64 64 64 64 64 64 64 64 6~ 64 64 *2,64 64, 64,' 64, .2~66 64, 64, 64, *2,64 04,:2,67 64, :2,6~ COMPANY : CHEvRor,.i USA I~}C .~.E.LL : $CU,".21~.-16 PAGE 9 **************************************~****:~************************************************************* *DEPTH '~AT. *PUR, POR. * CUM. * Ci..IM. ~ PER~. * PERM. * P~R~. * PERM, * CUM. * CUM. * CUM, C~AN * SAT. *EFF', *2~'~f) * EFF. * NC-FY ~I-:~.4'i'RI~, * L;A~ * OiL * ~:ATER * PERM. * PERM, * PERM, GRAIN ***************************************~***~************************************************************* * 46.3 * 8,7 * .03 · 0 * * 46,0 * e,'7 , .03 * 45,7 * 8.7 · ,1.':~ * o * * 45,6 * a,7 ~ .1] * 45,1 * ~.7 * 1,03 * 44.9 * 8,6 · 3.03 * 44.8 * 8,6 * ,61 * 44.5 * 8.6 ~ .35 * 44.3 * ',~.6 · .07 * 0 * * 43.7 * 8.6 * .19 * 43.b * 8,6 · ,95 * 43.4 * ~.6 , .17 * 0 , * 4~.1 * 8.6 * .01 ,~ .... ~ · * 42.B * 8,5 * 4,21 * 42.~) * 8.5 * 2.29 * 42.5 * 8.4 , 1.36 ~ 42.~ * 8.4 * .48 * 42.~ * 8,3 * ,09 * 42,0 * ~.3 * .15 * 0 * * 41.9 * 8,2 * .59 * 41,7 * 8,2 · b,03 · .33 * * 41.4 * 8.1 * 3.44 * ~1:.2 * 8,0 ; 3,~2 * 4~,0 * ~.0 * 5.25 * 40.;9 * 7,9 · 3,27 * 40.'7 , 7.,8 ~ 3,05 * 40,b * 7.8 ~ 1.53 * .05 * 40.3 * 7,8 g .90 * 4(.~.2 * 7, 7 * ,9~) , e.C.O , 7.7 * .~.31 * 3~.9 * 7.6 ¥ .Tq~ * , , , *10498 *100 *iL1.7 , , , *10501 *100 ,11,8 *10502 *100 ,12.8 * ,1050.3 * 91 *13.2 *10504 * 89 .13.0 *10505 *100 '11,7 * , * *10507 * 92 *1~,2 *10508 * 88 .15.2 0509 * 89 *16,b *10511 * 98 *l&.l * *10512 * 96 ,14.0 * *10513 *100 ,12,3 , , , · 0519 *100 *11,~ :~0520 * 98 '13.3 * *10521 * 97 '15,1 * *10522 * 99 ,13.4 * , 10523 * 85 ,14,2 '1,0524 *I00 *10~5 * ,' , , *10527 * 65 *13,0 * *10528 * 57 *17,9 *10529 * 63 *.1.7.0 * *10530 * 68 '16,2 * *10531 * 68 '14'.9 * 0532: * 77 *12, 9 0533 * 78 .13 3 * ,105'34 * 71 *1~ 9 * *10535 * 65 .17 9 ,105'36 * 66 I t 9 *10537 * 65 ,1,7 5 *10538 ~ 66 :*:17 5 ,1,0539 * 66 ,17 9 *10540 * 71 .1'72 *10541 * 71 ,17 o *10542 * 72 ,15 9 * *10543 * 74 *~.5 2 * *10544 * 69 ,15 3 *10545 * ~'~3 ,17.1 *10546 * 73 ,14.7 * , , , , * .03 * * .03 * 0 * .10 * * ,07 * * .05 * * ,04 * * * ,32 * * .52 0 * 1,80 * 0 , .53 * 0 * ,35 * 0 * ,28 * 0 · ,07 * , , 0 , ,07 * 0 * ,17 0 · ,81 * 0 * .16 * 0 * ,15 * 0 , ,01 * , 0 , 0 * ,02 * ,2! .01 * .19 * .01 * .,15 * 0 * .04 * 0 * ,01 * o , .02 * 0 , ,07 * .01 * ,79 * .0.1 * ,79 * .01 , .40 * .O1 * ,42 * .01 * ,81 * .01 * ,58 * .01 * .56 * 0 * ,27 (/ · * 16 * u * .1.1 ,01 * .30 * (.~ * .12 * , 23, 23, 23. * 23, * 23, 23, 23, 23. 23. 23, * * 3, * 23, * 23, 23, 2,,* 2,* 23 * 23 * 23 * 23 * 23 , 23 23 22 21 * 21 21, 21. * 21, ~[)EPTH WAT, *F'DR, , ', · -. . , * · SAT. *~ZF~. *'2~;) * EFF'. * )-~C-F"f *I~,:iRI:,~ * GAS * OIL, * ~ATE~ * PER~: · * * * * PC]R. * * * , · * GAS * *10550 *100 ,12,7 *10551 *lO0 *12.i , , *10555 * 91 '12,6 *10556 *10557 * 81 ,13.9 *10558 *10559 *10560 ~10561 ~X0562 ~X0563 *10564 * 79 ,14 7 *10565 * 76 ,10567 ,1.0568 * *10569 * 95 ,13 4 *10570* 98 *12.9 , , *10602 * 47 *10603 * 38 '12.e '10604 * 34 ,12.5 *i0605 * 40 ,12,5 *10606 *10607 *10609 * 33 :*i. 0610 * 31 '15 *10611 * 2g *1 5 , *10618 *: 29 .i,4 .1061g* 27 .14 ~1.062I 32 *1 *10622 * 33 .13, *10623 * *10624 * 37 .13 , * 39.4 * 39.3 , * 3g.a * * 3~,~ * 37,7 * 37.5 37,4 * 37,3 * 37,1 * * 36,9 * * 36.2 36,0 * 3~.9 35,7 35.5 * 5.l * * 33.8 =~ 33.7 * 33 · 5 * 33.4 * 33.3 7,b 7,6 7,6 * .15 7.6 7.5 ~ .27 * 7,5 7,5 7,5 7,4 '1,4 * 7.4 7.4 7.4 7.3 7.3* 7,3 7.3 7,3 7.2 7.1 * 71' 70* 69* 68* 1 6,7 * 6,6 * 1 ~,3 6.2 * 2 O.1 * 2 5,9 * 3 04 5.7 ~ 2:29 56* 5 5 ~, 229* 54* 255* 53* 133' 5 2 · 5 i * .35 * 5 1 * .55 0 0 0 .02 0 0 0 ,0! 0 0 .0 1 ,02 . Ol 0 0 0 0 ,OI ,05 ,06 ,05 .33 ,24 .33 ,61 .71 .73 .62 ,94 1,06 .90 .61 .5~ ,70 .32 .13 .06 33,~ ,12 * · 10625 * 37 * 33, * 5 0 ~: ,6,$ * .t4 * · I0627 * 35 *1~ 2 * * 32,7 * '' "' ~ .95 * 22 * ****************************************************** 0 * ,16 * 21, * 0 * .09 * 21, · * 0 * ,0@ * 21, * 0 * ,13 * 21, * 0 * ,06 * 21, * 0 , .45 , 21, 0 * .32 * 21. * 0 * .47 * 21, * 0 * ,29 * 21, * 0 * .16 * 21, 0 * .09 * 21, * 0 * ,21 * 21, * 0 * .23 * 21, 0 * ,06 * 21, 0 * ,20 * 21, * ,22 * () * 21, 0 . ,12 * 21, , 0 * ,08 * 21, , , 0 · 0 * 21, * .01 * 0 * 21, * ,01 * 0 * 21, .01 * 0 * 21. ,01 * 0 * 21, *' .02 * 0 * 20 , * .01 * 0 * 20 .01 * 0 * 20 ,02 * 0 * 19 * .02 , 0 * 19 * 02 · 0 * 1.8 .'01. * 0 * 17 .Ol * 0 * 17,. 02 * 0 * 16, .'02 , 0 * 15; .o2 * 0 * 14'~, * .02 * 0 * 13, .03 * 0 * 13, 02 * 0 * 12, * 02 * 0 * 12, Ol * 0 * 1t, * Ol * 0 * I1, o 1 , 0 * 11 .~ oi * 0 * 11, ol · o , .11' O1 * 0 * ******************** 50;, 50, 50,, * 0 , 50; * 0 *' 50, * 0 * 501 * 0 * 50, *. 0 * 50, ** , ***** L_._._..___J ,{ CO.~'~PAtqY : CHE~ROb, USA A~iIC ~,EbL : $Ci3-21h-16 PAGE , *10628 * 38 .14,5 $10629 * *10630 * 43 ,10.6 *10644 ~10645 *10646 * 57 *lO,b *10647 * 48 *10648 *10649 * 43 .13,7 *10650 *10651 * *10652 *10653 * 41 '13.5 *~0654 10655 * 10657 * 37 '10,7 0658 ~10659 ~: 0660 *i0661 0662 %10663 * 37 *'i6~7 0682 * * 11 ~10683 * 4~ *14 0684 * 53 *14' ~i0685 * 45 '12 * 10686 *10687 * 43 ~ 068~ * 42 *13 0 * 42 't2 *10691 * 43 '12 :~:I0692 * 4 *10693 * 40 '13 *10694 *10695 $ 44 'i3 10696 $10697 * 38 '13.7 :~I0698 * 37 '15,8 *10699 , .37 ,15,~ **************~********~**********************.*********************************************************** *DEPTH WAT ,POR. POR, * Ct!M. · CL)~.~. · PE~f,~. * PER~.~. * PER~, * PER~. * CUM. * CUM, * CUM. 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