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Home My WebLink About204-160 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ D Y- - 1 ft;¿ D Well History File Identifier Organizing (done) o Two-sided 11111111I1111111111 o Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: 0 Diskettes, No. ~reYSCale Items: ~ ~ 0 Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date q>~(}/OÞ 151 vvt{J Project Proofing BY: ~ 1111111111111111111 Date 7. ~jD / o~ 151 ~p Scanning Preparation BY: ~ x 30 = + Date q /30 / nb = TOTAL PAGES ~ ~ (Count does not include cover sheet) IA A . () 151 'VV\ T Production Scanning Stage 1 Page Count from Scanned File: d... 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:cr/30JDt:, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO 151 V4 f NO BY: Maria Date: 151 11/1111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • _~."p` _. ,u,v `.a~.~. ~ ~ ~T~~ ~,nj4 .alpF r~`µ: -'. MICROFILMED 03/01 !2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc RE: Tyonek Reserve 1 (API 50-283-10001-90) . . Howard, The original TR-1 well was drilled by Humble Oil in 1965 with API # 50-283-10001-00. I think the API # you are referring to was an application to re-enter and sidetrack that well by Aurora Gas but we have not done so to date and have no immediate plans to do so, at least not before 2007. Andy. From: Howard Okland [mailto:howard_okland@admin.state.ak.us) Sent: Thursday, September 28,2006 12:13 PM To: Andy Clifford Subject: Tyonek Reserve 1 ( API 50-283-10001-90 ) Andy, I need some help. Would please tell me if Tyonek Reserve 1 has been drilled? TNX Howard 1 of 1 9/28/2006 9:24 AM . (ill . FRANK H. MURKOWSKI, GOVERNOR AI,~tiliA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Duane H. Vaagen Project Supervisor Aurora Gas, LLC 1400 West Benson Blvd., Ste 410 Anchorage, Alaska 99503 Re: Tyonek Reserve # 1 Aurora Gas, LLC Pennit No: 204-160 Surface Location: 2078' FNL, 425' FEL, SEC. 5, T11N, R11 W, SM Bottomhole Location: BHL is in SEC. 4 Dear Mr. Vaagen: Enclosed is the approved application for pennit to re-enter the above referenced exploration well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the pennafrost or from where samples are first caught and 10' sample intervals through target zones. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-36 pager). reI BY ORDER ~ryHE COMMISSION DATED this~day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. · STATE OF ALAA I ALAS OIL AND GAS CONSERV~ON COMM ION PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas \"ù1i~. .....,"II,¡~sion 11b. Current Well Class: Exploratory 0 Development OilAn~riftêtiple Zone 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: Blanket0 Single Well 0 11. Well Name and Number: Bond No. NZS 429815 Tyonek Reserve 1 6. Proposed Depth: 12. Field/Pool(s): MD: 9845' TVD: 9845' Wildcat 7. Property Designation: C-61391 8. Land Use Permit: CIRI Agreement 9. Acres in Property: . 1a. Type of Work: Drill 0 Redrill 0 Re-entry 0 2. Operator Name: Aurora Gas, LLC 3. Address: 1400 West Benson Blvd., Ste 410, Anchorage AK 99503 4a. Location of Well (Governmental Section): Surface: 2078' FNL, 425' FEL, See 5, T11 N, R11W, SM Top of Productive Horizon: Same Total Depth: BHL is in See 4. 4b. Location of Well (State Base Plane Coordinates): Surface:x- y- Zone- 16. Deviated wells: Kickoff depth: nla Maximum Hole Angle: 18. Casing Program: Size Casing Specifications Weight Grade Coupling Hole RECFI\lf.:f) / AU(~ 1 g ?n04 ~ 13. Approximate Spud Date: 31-Aug-04 14. Distance to Nearest 2560 Property: 1500' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 14 feet Within Pool: N/A 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4430 Surface: 3347 Setting Depth Quantity of Cement Bottom c.f. or sacks 4 feet nla degrees Top Length MD TVD (including stage data) MD TVD 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD Structural Conductor 317' 20" 750 sks "A" Surface 3478' 133/8" 1380 sks "A" Intermediate Production 10194' 95/8" 720 sks "A" 10173' Liner Perforation Depth MD (ft): NA Perforation Depth TVD (ft): NA TVD o o 10173' Drilling Program W Seabed Report 0 Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date Contact Filing Fee 0 BOP Sketch 0 Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. P"nted N,meÍÀ ~':~ 1gen TiUe Project .'pe"'''''' wi F,bwe,the, E&P .e""œ., In'. Signature ( U -..- . ¡:.. E¿~"'J" Phone 258-3446 Date 18-Aug-04 ~ Y "\ Commission Use Only Permit to Drill IAPI Number: permit Approval Number: .z " 7' - / ~~ 50- 2. f 3 - / ð ð ð I ~ , t> Date: 0/ j/ S- /0 t.f Conditions of approval : Samples required Yes 0 NO.Þ( Mud log required Yes 0 No ~ Hydrogen sulfide measures Yes ~ No 0 Directional survey re~ired Yes::%. No 0 ~~Q Oþ..~d-S,CYSS""~) \J~\~">".>~1..Q~~Ù ~~'"' ..O~S,~) \... \ ') "'>~C>,. ~ \~"'~~ ~ BY ORDER OF THE COMMISSION 20. Attachments: Other: ßC ~ ~ 5< S'- Approved by: ORiGINAL Isee cover letter for other requirements. Date: ~~ðf ..--- Submit inDuplicate e e Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program . e Tyonek Reserve No.1 Re-Entry and Re-completion Backe:round Information and Present Condition All depths herein are referenced to original grade at 250.0' AMSL (Note, well records indicate GR as being both 230' and 250'). The well, Tyonek Reserve No. 1 was spudded by the Humble Oil Company on September 3, 1964. A 36" corrugated conductor was installed and cemented into place prior to moving in the rig. This was followed by drilling a 14 o/.¡" hole to 330', opening it to 26" and running 10 jts (297') of20" 94# H-40 STC casing and cementing it into place with 750 sacks of Class "A" cement. The cement properties were modified with the addition of 1750 Ibs of flaked mica. The conductor was drilled out with a 14 o/.¡" bit to 1894'. The well was then cored to 1921' with full core recovery. Following the coring operations, a 12 'l4" bit was picked up and surface hole was drilled to TD at 3490'. Wireline logs were run and a 14 %" bit was picked up and the hole was reamed to 3490'. This was followed by running 3464' of 13 3/8"casing (82 jts 54.5# & 3 jts of61# J-55), which was set at 3478' and cemented with 750 sacks Class "A" cement around the shoe and 630 sacks of Class "A" cement through the DV collar installed at 535'. Good returns were reported at surface when cementing through the DV collar. After setting surface casing, a 12 'l4" bit was picked up and the hole was drilled to TD at 10,194'. While drilling, the following intervals were cored: 3866' - 3893',6375'- 6402', 7890' -7903' and 7903' -7928'. Wireline logs were then run along with a SWS which retrieved 27 samples. After conditioning the hole, 10172' of9 5/8" casing (210 joints 40#, 31 joints 43.5# and 7 joints 47#) were run and cemented into place with 650 sacks "A" cement around the shoe. There is no record of the grade of casing. For this work, it will be assumed that the casing grade was J-55. After drilling out the shoe, 90 sacks of cement were placed at 10,185', the drillpipe was pulled into the shoe and another 70 sacks of cement were squeezed out around the shoe with an average injection pressure of 1000 psi and final pressure of 1600 psi. An 8 5/8" bit was picked up and drilling continued to 13,600' MD. The following intervals were cored: 10,194' - 10,202', 10,883' - 10,890', 11,641' - 11,644' and 13,414' - 13,432. The pipe became stuck while tripping in the hole at 11,312'. After running a free point survey, the pipe was shot and backed off at 10,176'. A decision was then made to suspend well work due to inclement weather. Permission was granted and 160 sx of cement were pumped down the drillpipe, through the bit and displaced to 10,658', a bridge plug was set at 10,000' and a 60 sx cement plug was placed on top of the bridge plug. It was proposed at that time to leave the well at that time with 14.9 ppg mud in the wellbore from 9845' to 100' and top offthe well with 100' of diesel. The decision was later made permanently abandon the well and a 20' cement plug was placed at surface. Due to brevity of available records, it is not clear ifthe well was indeed left with the 14.9 ppg mud and diesel as proposed prior to placing the 20' cement plug at surface. fàirweather E&P Services, Inc. Rev. 1.5 Page I of 10 8/18/2004 . e Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program Site Access and Lease Information . e Access will be via the existing road system. The original access road and well site will be cleared of brush and utilized. The pad is approximately 350' off ofthe main roadway. Other then the aforementioned clearing and minor road and pad repair, no new construction or disturbance is anticipated for the well work. The well is approximately 4 miles due west of the village of Tyonek. NOTE: The Tyonek Reserve No.1 is located on Lease No. C-61391. This well is within 1500' of Lease No. C-61392 which Aurora Gas, LLC currently owns as well with both leases being valid until 2/28/2006. Rit! Used for Proiect Aurora Well Service, Rig No.1 (A WS #1) will be used. This is the same rig Aurora Gas has been using for well work on other well work. Working floor elevation ~ 14' AGL. All equipment support equipment will remain the same with the exception of the blow- out preventer. If available, Aurora intends to use a 11" 5M bop, which will be configured the same as the 11" 3M currently in use. If not available, Aurora will use the 13 5/8" 5M stack which has been used previously for work performed on the NCD #3 well. The bop stack will be configured with a 11" 5M annular preventer, 11" 5M double gate with one set of pipe rams sized to the work string being used and one set of blind rams. This assembly will be set on top of an 11" 5M drilling spool. The 5M choke currently in place on the rig will continue to be used. ":> ~ ~ "-~ \ Geolo2ic Obiective dO ~b..-~ ~ç. O~ S l<è. ) \. \ '),,~) .\~, ~ St:S:::,(::) ('"'C't.~\",)'\~<=::' <z>-~~~\o..' Ç!. S ~~~ /0. . . u ~ \<t. <>~ . tIê- \ \(!. -.)(t(:) Þ ~\ .l "" ') <... \ ') I::H:- M By re-entenng the Tyonek Reserve No.1 well, It IS Äurora's mtent to eva1uate t1le c;. ( {--<J potential for commercial quantities of natural gas in the region. Aurorawill first evaluate t.!:o 't the potential for natural gas pay behind casing by running cased hole wireline logs. Any prospective intervals that warrant testing will then be perforated for flow testing. The primary geologic zones of interest are Carya sand intervals in the Tyonek formation with secondary objectives being in the shallower Beluga. Tvonek Reserve No.1 Re-entrv. Re-Completion Procedure A preliminary inspection indicates that the cellar is still intact, however; it appears to full of gravel to surface. According to records available, a 12" series 900 casing head (commonly now known as a 13 5/8" 3M head) is installed with a cap welded over the stub end ofthe 9 5/8" casing and the P&A marker post welded on to the top ofthe cap. In order to effectively re-enter and re-complete the Tyonek Reserve No. 1 as a gas production well in accordance with AOGCC regulations, the following tasks must be completed: 1. Clean and repair access road and drillsite as necessary to allow access and room for the rig and well work activities. Fair1j1eather E&P Services, Inc. Rev. 1.5 Page 20flO 8/18/2004 e e Aurora Gas, LLe. Tyonek Reserve No.1 Well Re-Entry Program . e 2. Excavate out cellar and inspect condition of and type of wellhead equipment present. If old wellhead equipment is still evident after digging out cellar, clean, inspect and test for pressures. If salvageable, install new 13 3/8" 3M x 11" 5M casing spool. 3. MI/ RU A WS Rig No.1, install and test II" 5M BOPE to 250 / 5000. BOP equipment will consist of (1) 5M annular type preventer, (1) 5M rated double gate ram type preventer with one set of pipe rams sized to work string being used and one set of blind rams, drilling spool and 5M rated choke manifold. Test gas detection and PVT systems to ensure proper function. Prepare recycled 9.5 ppg mud system. 4. PU 8 1/2" bit and collar, drill out 20' cement plug at surface and monitor for pressures and flow. Follow by cleaning wellbore to top of the cement plug at 9845'. Pressure test casing to 2000 psi, which is -50% of the pressure rating of the lowest grade segment of the 9 5/8" casing string. Remediate with squeeze procedures as required. Clean out wellbore with bit and casing scraper and proceed with cased hole logging program. 5. Rig up and run suite of cased hole wireline logs including a CBL type log to verify/locate cement location(s). 6. Analyze logs and prepare for either perforating and testing; or if required, further perforating and cement squeeze procedures to isolate potential pay zones prior to perforating and testing. Isolate potential pay intervals as needed by selectively perforating and squeezing, performing a block squeeze both above and below potential pay intervals. Block squeeze to be performed by first perforating the casing with a casing punch type charge, placing retrievable bridge plug below the perforations, placing 2 bags of sand on top of the plug and squeezing cement into the èasing annulus. 7. Perforate and test well as determined by wireline logs to - 9840'. 8. Based on test results, zones of non-interest will be either isolated with bridge plugs and or cement (if below pay) or squeezed off with cement prior to running completion. 9. If testing results and log interpretation indicates sufficient reason, attempts may be made to stimulate zones of interest with fracture / acid treatments. In the event, testing proves the well non-commercial, a verbal request will be made for permission to P&A the well immediately and a Sundry Application will be submitted as soon as is practical thereafter. 10. Run completion which will consist of sand exclusion type screen spaced out to cover pay intervals hung off below a 9 5/8" retrievable type production packer. A Fairweather E&P Services, Inc. Rev. 1.5 Page 3 of 10 8/18/2004 . e Aurora Gas, LLe. Tyonek Reserve No.1 Well Re-Entry Program sliding sleeve will be installed ~ 1 tubing joint above the seal assembly and an "X" landing nipple will be installed 1 joint below the packer. At this time, Aurora intends to run 2 7/8" 6.5# 8rd EVE J-55 tubing as final production string. Depending on results of re-entry and test, Aurora may opt to resize to 3 Y2" production string. . e 11. Run, space out and land production tubing. PU and circulate, displace tubing annulus with O2 inhibited brine, land tubing and lock in place. Install blanking plug in profile nipple, test tubing to 2500 psi. 12. ND BOP, NU production tree valve assembly, install BPV, pressure test tree to 5000 psi. Pull BPV, pull blanking plug. Attachment II illustrates proposed completion. 13. Swab in well, flow to clean up and test after running completion. Record results, install BPV and release rig. 14. File Form 10-407 indicating final well configuration and status. Tvonek Reserve No.1 Pressure Considerations The area has had considerable exploration activity for oil, with limited testing for commercial quantities of natural gas due to market conditions existent in the 1960's, 1970's and 1980's. However; information available from more recently drilled offset wells nearby, namely the Simpco Moquawkie No.(s) 1 and 2 as well as the Mobil Moquawkie No.1 and Lone Creek No.(s) 1 and 2 indicate that on average, a pore pressure gradient of .45 psilft for the region is reasonably accurate and conservative for well design and safety purposes. It should be noted that while there are anomalies in the region, the Tyonek Reserve No. 1 was drilled and is currently cased and there is no mention was made of pressure or well control problems in the drilling records available. The pore pressure gradient of .45 psi I ft is equivalent to 8.65 ppg mud. Based on this information, it is believed that a kill weight brine of9.2 ppg should be sufficient for perforating and well kill fluid. Maximum Anticipated Surface Pressure The maximum anticipated surface pressure (MASP) for zones of interest behind the 9 5/8" casing, can be calculated by subtracting the gas gradient from the predicted pore pressure for the TVD depth at TD. Using a pore pressure gradient of .45 and a gas gradient of .11, the MASP can be calculated as follows: Gas Gradient ~ .11 Pore Pressure Gradient ~ .45 ( conservative estimate) => Maximum anticipated Surface Pressure = Depth(tvd) x (PPG - GG) => 9845 x (.45 - .11) = 3347 psi. .Fairweather E&P Services, Inc. Rev. 1.5 Page 4 of 10 8/18/2004 . e Aurora Gas, LLe. Tyonek Reserve No.1 Well Re-Entry Program . e For perforating, a filtered KCL brine weighted to 9.2+ ppg will be used. Prior to perforating procedures, wireline BOP's and a lubricator will be installed and tested. Perforating and testing will reveal actual pressures prevalent to the area and zones of interest, kill weight brine density will be adjusted accordingly. When perforating the 9 5/8" casing, caution needs to be exercised to control and monitor pressures should the pore pressure gradient be higher than predicted. An II" (5M) BOP system will be used, BOP tests will be perfonned to 250/5000 psi or other as dictated by the approved PTD. Please see attached diagram of BOP system Drillin2 / Workover Fluid Proeram and Properties: Recycled drilling muds will be used while drilling cement plugs inside 9 5/8" casing and cleaning out debris to 9845'. These fluids will be augmented with gel and polymer as needed for high vis sweeps required to maintain hole cleaning capabilities. Muds will be weighted to 9.5 ppg to ensure that should trapped pressures be encountered, potential well control problems are minimized. Prior to perforating, the well will be swapped over to filtered brine, weighted to 9.2 ppg or other, as dictated by discoveries made during well re-entry. W orkover and completion brines will be made up with 3 % KCI minimum composition and may be augmented with additional KCI, NaCI and NaBr as required and detennined while working on the well. Should the well prove commercial, the annular area above the completion packer will be filled with an O2 inhibited KCI brine. Barite will be readily available as a weighting agent if required. Drillinp' Fluid System: A WS pit system as currently configured, shale shaker, PVT monitors. Drillinp' / Well Re-Entry Hazards: Abandoned well re-entries offer a number of challenges, among them the potential for junk in the hole, mechanical degradation of casing strings, and trapped pressures below plugs. Drilling in the South Central Region of Alaska offers challenges as well, the most notable being shallow gas hazard and stuck pipe in the numerous coal beds present. Work on the Tyonek Reserve No. 1 will entail cased hole operations only so the stuck pipe hazard due to coals should hopefully be eliminated. The common known hazards are as follows: Shallow gas: Shallow gas is a known hazard which exists throughout the region. The northwest side of Cook Inlet is noteworthy for its shallow gas hazard. The Fainjleather E&P Services, Inc. Rev. 1. 5 Page 5 0/10 8/18/2004 . e Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program All responsible personnel will be made aware and a notice of such hazards will be posted in the rig doghouse. There is no record ofH2S in the region, however; a gas detection system capable of detecting H2S as well as methane will be installed on the rig with detectors at the floor level, the shale shaker and in the cellar. . e Junk in hole: It is not improbable that one could find discarded steel and other assorted junk which was thrown "down the hole" at abandonment time. Drillers need to be aware ofthis when drilling. If sudden torque and ROP changes occur, this may be the reason and the company man needs to be notified immediately. Collapsed / burst casing: Re-entering an old well is always an unknown. While not likely, the potential exists that casing damage has occurred, either through some type of corrosive action, some time of mechanical deficiency or possibly even because of seismic activity. At the least, this could cause a minor inconvenience and require cement squeeze procedures. At the worst, safety could be compromised should high pressure gas broach the surface through a leak. Here again, well conditions need to be monitored very carefully. Fain-Feather E&P Services, Inc. Rev. 1. 5 Page 60/10 8/18/2004 · e . e Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program Tvonek Reserve No. 1 Summary of Drillina Hazards POST THIS NOTICE IN DOGHOUSE -v There is potential for pressure below surface plug. -V Possibility of junk in hole from original P&A procedure. -V There is potential for pressure below cement plug at surface. -V Potential for unsound casing, either from corrosion, mechanical failure or seismically induced weakness. -V There is a chance that higher than normal pore pressure gradient (>.45 psi I ft) may be encountered while perforating. Have sufficient kill fluid materials ready and standing by for well kill operations. -V There is no H2S risk anticipated for this well. PLEASE SEE: TYONEK RESERVE NO.1 WELL PLAN FOR ADDITIONAL INFORMATION. Fairweather E&P Services, Inc. Rev. 1.5 Page 7 of 10 8/18/2004 Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program 20' Cement Plug at Surface Tvonek Reserve No.1 Current Configuration per available records. Mud log indicated well drilled with 10.5 - 10.8 ppg mud. Well reportedly left with 14.9 ppg mud in well bore? ----. 1139' fish in hole from 10173' -11312'. Fish is 11 518" bit, 6" sub, drill collars, crossovers, 4" drill collars, drill pipe, crossovers and safety joint. Cemented into place by pumping 160 sx "A" through bit before backing off. TOC ato 10658'. ~ Ji'airweather E&P Services, Inc. Rev. 1. 5 20" 94# conductor set at 317'. Cmtd with 750 sx "A" with good returns reported at surface. 630 sx "A" Througb DV collar at 525' wi returns reported at surface. 13 3/8" 61# & 54.5# Casing to 3478'. Cmtd with 750 sx around shoe. Est. TOC at 7479' in 9 5/8" x 12 y." annulus (BEST CASE SCENARIO) ------, Cement Plug on top of bridge plug 9845' - 10,000' Halliburton Bridge Plug @ 10,000 ' 12 Y." bole to 10,194'. 9 5/8" csg at 10194'. (210 jts 40#, 31 jts 43.5# & 7 jts 47#) Cmtd with 720 sx "A" No record of returns at surface Attachment I TD 8 518" bole @ 13,600' Page 8 of 10 8/18/2004 Aurora Gas. LLe. Tyonek Reserve No.1 Well Re-Entry Program 15.8 ppg "G" cement squeezed down'} 5/8" x 13 3/8" annulus .Tvonek Reserve No.1 Proposed configuration after Fe-entry and completion Sliding sleeve installed -30' above retrievable seal bore type packer and X profile landing nipple located -30 below packer. 9.2+ ppg completion packer fluid above retrievable production packer. 4 W' Sand Exclusion screen to be spaced and installed across all perforated intervals. Screen will be hung off below packer sealbore assembly. Exact perforated interval to be determined. 1139' fish in hole from 10173' -11312'. Fish is 8 5/8" bit, 6" sub, drill collars, crossovers, 4" drill collars, drill pipe, crossovers and safety joint. Cemented into place by pumping 160 sx "A" through bit before backing off. TOC ato 10658'. Fainveather E&P Services, Inc. Rev. 1.5 III D 2 7/8 6.5 #/ft J-55 production tubing 20" 94# conductor set at 317'. Cmtd with 750 sx "A" with good returns reported at surface. DV collar at 525' on 13 3/8" surface casing. 13 3/8" 61# & 54.5# Casing to 3478'. Cmtd with 750 sx "A"around shoe and 630 sx "A" through DV collar located at 525' with good returns reported at surface. 95/8" casing to be perforated .c-- and squeezed as necessary to insure proper pay isolation. -- ~ i --:- Est. TOC at 7479' in 9 5/8" x 12 v.." annulus (BEST CASE SCENARIO) Cement Plug on top of bridge plug 9845' -10,000' Halliburton Bridge Plug @ 10,000 ' 12 W' hole to 10,194'. 9518" csg at 10194'. (210 jts 40#, 31 jts 43.5# & 7 jts 47#) Cmtd with 720 sx "A" No record of returns at surface Attachment II TD 8 5/8" hole @ 13,600' Page 9 of 10 8/18/2004 · e . e Aurora Gas, LLe. Tyonek Reserve No. 1 Well Re-Entry Program Pertinent Well Infonnation & Specifications: 13 3/8" Casine:: Weight (lb/ft) 54.5 61 9 5/8" Casine:: Weight (lb/ft) 40 43.5 47 Grade * J-55 J-55 Collapse 1130 1540 Yield 514,000 595,000 Burst 2730 3090 Grade ** K-55 K-55 K-55 Yield 452,000 691,000 746,000 Burst 3950 4350 4720 Collapse 2570 3250 3880 ** Used lowest ratings available due to unknown grade of casing. 2 7/8" Tubing: Weight (lb/ft) Grade Burst (psi) Collapse (psi) Yield (lb) 6.5 ** J-55 7260 7680 99,700 6.5 N-80 10,570 11,160 145,000 3 1/2" Tubine:: I Weight (lb/ft) I Grade Burst (psi) I Collapse (psi) I Yield (lb) 9.2 ** N-80 10,160 10,530 207,000 ** Indicates tubing size/wt/grade currently in stock. Estimated load assuming tubing to 8500' and completion weighing 5500 Ibs. @2 7/8" tubing: (6.5 lb/ft * 8500 ft) + 5500 lbs = 60,750 lbs. J-55 Safety Factor: N-80 Safety Factor: 99,700 lbsl ((6.5 lb/ft * 8500 ft) + 5500 lbs) = 1.64 145,000 lbsl ((6.5 lb/ft * 8500 ft) + 5500 lbs) = 2.38 @ 3 1/2" tubing: (9.2 lb/ft * 8500 ft) + 5500 lbs = 83,700lbs. Safety Factor: 207,000 lbs I ((9.2 lb/ft *8500 ft) + 5500 lbs) = 2.47 Note: Above calculations do not include compensation for buoyancy effects. Fairweather E&P Services, Inc. Rev. 1. 5 Page 10 of 10 8/18/2004 . e . e Modified Load Bearing Bell Nipple II" 5M BOP setup proposed for use on Tyonek Reserve 1 Re-entry 11" 5M Drilling spool w/3"5M manual and hydraulic choke and kill valves and lines mounted on each side. ~ fl.·.·...·.······.·.·. \7 ·ü L Aurora Gas, LLC 11" 5M Annular Preventer 11" 5M Double Gate BOP 1 Set of blind rams and 1 set of pipe rams sized to fit work string in use. .1...·...·.·.··..··.\711....·."................... ··ü- 11" 5M x 13 5/8 5M tnbing head assembly 13 3/8" 3M Casing Head (Currently in Place) I Tyonek Reserve BOP I Drawing Not To Scale I 12-Aug-04 Rev. 1 dhv hL. ~ ... lyull~1\. Kesel ve No.1 Update--Ignore that message . . Subject: RE: FW: Tyonek Reserve No.1 Update--Ignore that message From: duane vaagen <duane@fairweather.com> Date: Mon, 13 Sep 2004 17:20:30 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom: As indicated below, the regs do indicate a BOP system with 3 sets of rams be used. Based on that, Aurora Gas, LLC intends to rent an 11" 5M stack with a double-gate and one single ram set-up. This will likely be the only way they can get a stack that will fit under their floor. The stack will employ one set of blinds, and two sets of pipe rams sized to fit the workstring being used. Should this change at a later date, Aurora will notify the AOGCC. If when the time comes, an 11" 5M stack is not available, we may have to look at other options. I apologize for the length of time it took me to respond on this matter. Duane Vaagen Fairweather E&P Services, Inc. 258-3446 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, August 30, 2004 12:23 PM To: duane vaagen Subject: Re: FW: Tyonek Reserve No.1 Update--Ignore that message I went back in my sent file and found that I had sent you a prior message. Sorry about that. Tom Thomas Maunder wrote: Hi Duane, I left you a voice message. I know this well has slid on the schedule. You are proposing to only employ and annular, 1 set of blind rams and 1 set op pipe rams. I don't remember if we talked on this or not. Your MASP is greater than 3000 psi so the planned stack rating is correct, but as I read the regs you need another set of pipe rams. Give me a call when you get back in and we can talk. Tom Maunder, PE AOGCC duane vaagen wrote: Mr. Tom Maunder: I have been notified by Aurora Gas LLC, that they intend to defer the Tyonek Reserve No. 1 project until next spring or summer. They have opted to focus on the Three Mile Creek Unit No. 1 and Aspen 1 prospects, the permit applications of which will be submitted soon. I know that you have been fast tracking your review of this project and I appreciate your consideration for timely turnaround of the permit. I am writing to let you know that our schedule is now less immediate and turnaround of the Permit To Drill can be done at your convenience. Would you please pass this on to anyone else that may be working on this permit. At this time, Aurora's plans appear to be as follows: Three Mile Creek Unit No.1 (Late September, early October start?), Aspen No.1 lof2 9/14/20047:06 AM Kb: t W: 1 yonek Reserve No.1 Update--Ignore that message 2of2 . . (immediately following TMCU 1). Aurora is considering the use of either the Kuukpiq 9 or Nabors 129 for these projects, pending rig availability. Aurora is also in the process of preparing the AWS 1 rig for de mob back across the Inlet at this time. They may attempt to work on the Cohoe 1 well near Kasilof, but I haven't heard any mention on that lately. I am finalizing the PTD paperwork for that one as well. On another note, I received your reminder concerning the Sundry Notice for the P&A of the Long Lake No.1. I should be able to get that to you by tomorrow. Thank You, Duane Vaagen Fairweather E&P Services, Inc. 2000 East 88th Avenue, Suite 200 Anchorage, AK 99507 907-258-3446 9/14/20047:06 AM r W. lyonek Reserve No.1 Update . . Subject: FW: Tyonek Reserve NO.1 Update From: duane vaagen <duane@fairweather.com> Date: Wed, 25 Aug 2004 09:23:38 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Mr. Tom Maunder: I have been notified by Aurora Gas LLC, that they intend to defer the Tyonek Reserve No.1 project until next spring or summer. They have opted to focus on the Three Mile Creek Unit No. 1 and Aspen 1 prospects, the pennit applications of which will be submitted soon. I know that you have been fast tracking your review of this project and I appreciate your consideration for timely turnaround of the pennit. I am writing to let you know that our schedule is now less immediate and turnaround of the Pennit To Drill can be done at your convenience. Would you please pass this on to anyone else that may be working on this pennit. At this time, Aurora's plans appear to be as follows: Three Mile Creek Unit No.1 (Late September, early October start?), Aspen No.1 (immediately following TMCU 1). Aurora is considering the use of either the Kuukpiq 9 or Nabors 129 for these projects, pending rig availability. Aurora is also in the process of preparing the A WS 1 rig for demob back across the Inlet at this time. They may attempt to work on the Cohoe 1 well near Kasilof, but I haven't heard any mention on that lately. I am finalizing the PTD paperwork for that one as well. On another note, I received your reminder concerning the Sundry Notice for the P&A of the Long Lake No.1. I should be able to get that to you by tomorrow. Thank You, Duane Vaagen Fairweather E&P Services, Inc. 2000 East 88th Avenue, Suite 200 i\nchorage,AJe 99507 907-258-3446 1 of I 8/30/2004 12:01 PM BOP for Tyonek Reserve . . Subject: BOP for Tyonek Reserve From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 23 Aug 200414:38:03 -0800 To: Duane Vaagen <duane@fairweather.com> Duane, I am reviewing the APD packet for Tyonek Reserve. The MASP for the well calculates out to exceed 3000 psi, hence a 5000 psi WP stack is needed. This is as you plan. However 20 MC 25.035(e) (1) (B) (i) requires that 5000 psi WP stacks include 2 sets of pipe rams rather than the one set proposed. If there is insufficient room to fit another set of 13-5/8" under the rig, you need to request a variance per (h) (1) of that reg section. Will an additional set of II" rams fit?? There is another drilling operation in South Alaska where there is insufficient room for the required 13-5/8" stack. The mitigation measure for that operation is running variable bore rams to give the maximum flexibility to cover tubulars. Please call and we can discuss. Tom Maunder, PE AOGCC 1 of 1 8/30/2004 12:23 PM Aurora lease verification . . This will serve as verification that Aurora Gas, LLC. has 100% operating/working interest in CIRI oil&gas leases C-061391 and C-061392. The legal descriptions for each lease are as follows: CIRI Oil&Gas Lease C-061391: Township 11 North, Range 11 West, Seward Meridian That portion of U.S. Survey 1865 more particularly described as (protracted); Section 5; All; Section 6; All; Section 7: All; Section 8: All; containing approximately 2,560 acres. C-061392;Township 11 North, Range 11 West, Seward Meridian That portion of U.S. Survey 1865 more particularly described as (protracted): Section 3: All; Section 4: All; Section 9: All; Section 10:AII; containing approximately 2,560 acres. Please inform if you require any further information. Teresa Ressler ClR] Natural Resource Mgr. Direct: (907) 263-5111 Fax: (907) 263-5190 EmaiI: tressler@ciri.com 1 of 1 8/18/20043:43 PM . . . e - "" --.-..¡ -- -...- \¡,~ - -II. E & P SERVICES, INC. 12-Aug-04 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RECE\VED AUG 1 8 2004 I, 0'\ & Gas Cons, CommisSìor Alas"a I Anchorage RE: Re-application for Permit to Drill: Re-entry of Tyonek Reserve No. 1. Dear Mr. Norman: Aurora Gas, LLC hereby applies for a Permit to Drill, a prerequisite for re-entering, and performing work on an abandoned well. It is Aurora's intent to re-enter, log, test and evaluate the potential for natural gas reserves in the Beluga and Tyonek sand intervals penetrated by Tyonek Reserve No.1 wellbore. The Tyonek Reserve No.1 was drilled by Humble Oil and Refining Company in 1965 in search of oil. The well was abandoned 400' short of reaching the permitted TD due to a lost BHA in the hole. It was proposed at the time to return the following summer and complete the drilling but a decision was made in the interim to P&A the well. Tyonek Reserve No.1 is in an area to the east of the Moquawkie and Kaloa gas fields. The well is located onshore approximately 5 miles northwest of the village of Tyonek. Surface and minerals are managed by the Tyonek Native Corporation and CIRI respectively. Aurora plans to begin well re-entry and re-completion operations on August 31, 2004, The site is readily accessible via road so no new roads are required. Upon receipt of all necessary permits and approvals, contractors will clear the location of overgrowth and repair the surface. If necessary, a new wellhead will be installed and the rig, Aurora Well Service No.1, will be rigged up over the well to commence well operations. Pertinent information in and attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill- 2 copies 2) Fee of$100.00 payable to the State of Alaska 3) Diagrams and description of the BOP equipment to be used as required by 20 AAC 25.035 (a)(1) and (b) 4) The drilling fluid program, in addition to the requirements of20 AAC 25.033 is attached 5) A copy of the well history, proposed re-entry, re-completion procedure and operational considerations is attached. OR\G\NAL 2000 East 88th Avenue' Anchorage, Alaska 99507 . (907) 258-3446' FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505' Houston, Texas 77060' (281) 445-5711 . FAX (281) 445-3388 ~_. e . e Mr. Norman Contd. . . 6) A Summary of Potential Well Hazards. 7) Pressure Information This application is being submitted on behalf of Aurora Gas, LLC by the undersigned and any questions or concerns can be directed to same. Alternately, Mr. Ed Jones, Vice President of Operations and Engineering can be contacted directly at (713)977-5799. Duane H. aagen Project Engineer Fairweather E&P Services, Inc. Attachments cc: Ed Jones Andy Clifford FAIRWEATHER EXPLORATION & PRODUCTION SERVICES INC. - GENERAL ACCOUNT Fairweather E&P krViees ... ... 13 ( VENDOR ID ' AME _, PAYMENT NUMBER ICHE TEl __ 016 1049 TATE OF ALASKA AOGCC (OIL & G 00012450 ~/16/2004 OUR VOUCHER NUMBER YOUR VOUCHER NUMBER DATE AMOUNT AMOUNT PAID DISCOUNT WRITE-OFF 00016517 1049040816*TYONEK 8/16/2004 $100.00 $100.00 $100.00 $100.00 COMMENT 13016 l NET '\ $0.00 $0.00 $100. RJ:('t::"c, '~!) AUG } t 7004 Alaska Oi¡ & Gas (,)n~. ...u.....;¡;.sion Anchof age $0 00 $0.00 $100.00 OJ - .-- "___'___<__é__"_~' ~_,~_~ "_~__,,,_ 13016 FIRST NATIONAL BANK A LAS K A 89-6-1252 One Hundred Dollars And 00 Cents TO THE ORDER STATE OF ALASKA AOGCC (OIL & G OF 333 WEST 7TH AVE SUITE 100 DATE AMOUNT 8/16/2004 $100.00 6 ¿{£ M' ANCHORAGE AI< 99501 USA -------------------------- 1110 ¡. ~ 0 H:J III I: ¡. 2 5 2000 ¡; 0 I: 0 ¡. ¡. 2 B 2 ~ 0 III FAIRWEATHER EXPLORATION & PRODUCTION SERVICES INC. - GENERAL ACCOUNT Fairweather E&P ¡erVieCs Ine ( VENDOR ID I 'NAME PAYMENT NUMBER CHECK DATE 1049 TATE OF ALASKA AOGCC (OIL & G 10012450 J/1,,/7004 I OUR VOUCHER NUMBER YOUR VOUCHER NUMBER DATE AMOUNT AMOUNT PAID 00016517 1049040816*TYONEK 3/16/2004 $100.00 $100.00 $100.00 $100.00 COMMENT -~_._---~.~-~~---,,---------------- ~.~----------~--_._-- 13016 13016 l DISCOUNT WRITE-OFF NET '\ $0.00 $0.00 $100.00 $0.00 $0.00 $100.00 . e . e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ ~r-¥'~ -!i PTD# ;:¿o L/ - / he:> Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (1f API number last two (2) digits are between 6.0-69) X Exploration Stratigraphic ~'CLUE'" Tbe permit is for a new weUbore segment of existing well' . Permit No, . API No. Production. should continue to be reported as a function 'of tbe original API number. stated above. HOLE ]n accordance witb 2.0 AAC 25..o.o5(f), aU records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (5.0 7.0/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fun compliance witb 2.0 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:sception. {Company Name) assumes tbe liability of any protest to the spacing .exception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 3.0' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals through target zones. PTD#:2041600 Company AURORA GAS LLC Initial ClasslType 1 P~rmitJee é!ttacheJ:L . . . Y~s . 2 .Lease.nµmber .appropriate_ . . _ . . _ . . . . . . . . . . . . Xes 3 _UJllqµe weltname_and lJl!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 4 WellJQcat~d in_a_clefioed_pool_ _ . . . _ . . . _ _No _ EXf>L.oRATORY RE:ENTRY_Of'A PM'd OIL_EXPLOAATfONWELL 5 WeUJQcated Proper .dlstance from driJling uoitb.oµod_aIY Xes . . _ _ _ _ _ . _ 6 WelllQcated prpper .dlstançe. from QtbeJ weUs_ _ _Y~s _ _ . 7Sutficieot acreage_ayailable indrillilJg l!njC _ Y~s _. _ _ . _ 8 Jfd~viÇlted, js_ weJlbQre platiocJuded . . . .NA 9 .Qperator ol1ly affeçted party _ . Yes . . _ . . _ . 10 .O-perator bas_approprlate.Qond lnJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit CßO be lSSl!ea wjtbQut com¡erva_tion order _ _ Y~s Appr Date 12 P~(TTIit c.ao be lSSl!ea wjtbQut é!Qmir1istratÍ\le apprpvaJ _ . . _Yes RPC 8/18/2004 13 Can permit be approved before 15-day wait Yes 14 WeJIJQcat~d wlthin area and strata authorized bylojectiolJ Ord~r # (pµUO# in cDmmeots) (For .NA _ . _ _ . . . _ _ . . _ _ _ _ _ _ _ 15 _All wel1s_ witÞtn Jl4_roile_area_of review jd~otified (Fpr ~efVjc.ewe!l ol1ly) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ.cecl injector; ~urationof pre-propuctiolJ I~$~ th.m3 mOl1tbs (For.servtce well Qnly) . _NA . . _ . _ _ . . _ _ . _ _ 17 ACMP.f'indingofCQnßisteoçyh_as bee_nissued.forJbis project. . . _ . _ _ NA _ . 18C.oodu.ctor stríl1g_pJQvided _ _ . _ . _ _ . _ _ NA _ . _ Condµçtor _striJlg set jn QrgilJi:!J well. _ . _ 19 .surfaœcÇlsil1g.PJQtec_ts alLknown USQW~ _ _ . _ _ . . _ . . . . _ . . . NA _ . Surface castng ceroentedtQ surface. aCCQrdiog to .origilJaJ well.recorQs, _ . 20 .CMT vDl adeQuateJo circulate oJl_cooductor & Sltrf.csg . . . _NA _ _ . Surface casiJlg ceroente_d to su.rface_ aCCQrCiog tp .origilJaJ wen records, 21 .CMTvoladeQltateJotie-lnJong.stringto_S!.lrfcsg_.. _ . . _ . . _ . . No. . _ _ . _ _ 22 _CMTwil! çoyecaJll<oown.prodµctiye bQri~ons_ . Y~S. . _ _ . _ _ 23 _Cßsiog designs aeiequa.te for C,T, ß&.perroafrosL . . _ .Y~s _ _ _ _ . _ . . _ _ . _ _ . _ _ . _ _ . . 24 Adequate.tankÇlge.or re.serve pit. . . . _ . . . . Xes. . _ Rig js.eqµipped.with stee1pjts.. No rßserllepjt-planlJed, Wasteto I:lJvjrotech.. . _ . 25 Jf.aJe-prilL has.a l0:403 for abandonmeJlt be~o apprQvßd ... . . . . . . . . . _NA. .... _ . . _ . . . . 26 Adequate_we!lbore~eparatjoJl_proPO~ep _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ NA _ _ _ _ _ . _ Wod<j~ within_prior_a.balJd.ooed_weJI._ No new Crilllng plalJl1ed._ . . _ _ . _ _ . _ _ . . _ . _ _ . . _ _ _ _ . _ _ _ . _ _ . _ 27 Jfdjverter Jequired, dQes jLmeet rßguJatioos. _ . . . NA . . . .. ~II WQrk will Þe CQnpYC<led with .stack in place.. . _ . Appr Date 28 _DJilIiogfJujd_programsc.hemÇltic.&eq.uipJistadequale... ........ _ Yes. _' . . MÇlximumexpected Bt:if>8.6EMW..f>lannedtnttiÇlLmu_dweight9..5fDu~:ent~. TEM 9/15/2004 29 .BOPEs,d.othey meetrßguJatioo . _ . . Y~s. . . SinçeMASf' is?' _30QOpsi, SQOOpsi3.ram_stack with_annylarj~ ne.eded.. . . _ . 30 .BPPE_pr~ss ratiog appropriate: Jest to.(puJ psi9 in.commßnt$). . . .Yes. . _ . . . . CalculatedMASP.33~? psi.. Planned BOP Jest pressure500Q psJ.. . 31 _Choke manifold cQmplie~ w/APtRf'-53 (May 84)_ . . Yes . . _ . . . . _ . 32 WQrk will occur. withoyt.operationsbutdown. _ .Y~s . 33 .Is. presençe of H2S gas. probablß . . . . . _ _ . No. 34 MeclJanicalconditlon .of w~lIs within ~Qß verified (For.serviœ wßI) only) _ . . NA Administration Engineering Yt~\~ -', -..Jl.!UAlIVl\.h:::, UNut:rINED GAS - 528500 Well bore seg Annular Disposal Well Name: TYONEK RESERVE 1 Re-entry EXP /1-GAS GeoArea 820 Unit 00000 Program EXP On/Off Shore On - - - - - -- - - - - - - - - - - - - - · There is a ç/)ançe of.H2S.dµe to"old"ml!d.s.ourjng.since ab.ando.nmeot Rig.h_as sensors ßoei alarms.. . Geology - . - - -- Appr RPC Date 8/18/2004 - - - - - - 35 P~rmit. cao be issued wlo hydr.ogen. sulfide meaSUres. 36 .Data_pJesßoted Qn. pote.ntìal .oveJPre~sµrezones _ . . 37 .S~i.smic.aJlalysjs Qf slJaJlow gaszooes. 38 Seabed .cOl1djtioo sl!rvey(if off-shDre) . 39 . CQnta.ct.namelpÞoneJorweekly progress.reports [e¡cploratory .only]. ... _ No .Yes NA. NA _ .Yes . . _ . EVEN Tt:iOUGt:i THE ORIGIN~l WEI-l OtD.NOl: RECORO A~Y H2S GAS, f>RECAUT!ONS WILL.BE . . REQUIREO FOR. THJS RE-_ENTRY._ TH_E ORIGlNAL WEL.L_ENCPUNJI:REO NORMAl- PORE PRESSURES.. _ TljE ~BANOIO~EO WELL MAYHA VE GAS fROM A PEEP .ZONE_TRAPPI:O BY A CEMENT f>L.UG. . · Tlj/SSJl:UAJIQN COUlO C~USE ~N OYER",BALANCEO CONOIT!ON WHEN DRILLING ~ PI-UG.. · TlJE OPEAANR 1$ AWARE Of ntE POTENML ntREAt ~ ~A. c,. \ \'7 - - - - - ~ - Geologic V Engineering CommiBiqn~r: ...... .....D. ate: C' ? C. ommissioner: ("11"':'''''''''- ;'"', ,,"'¡!::'Þ 11 oÄN's1rN'l {lfprfl tJ30~' W1 Date o o . e . -