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167-007
By Samantha Carlisle at 1:16 pm, Sep 30, 2020 AMAROQ RESOURCES, LLC 9/30/2020PRODUCTION WELL MECHANICAL INTEGRITY TESTSWELL NAME PTD WELL COMPLETION MIT‐T MIT‐T MIT‐T MIT‐IA MIT‐IA MIT‐IA TIFL TIFL# TYPE DATE DATE PRESSURE PASS? DATE PRESSURE PASS? DATE PASS?(psi) (psi)Nicolai Creek Unit #2 166‐038 Gas Prod 10/11/13 10/9/2013 2000 Y 10/9/2013 2000 Y NA NANicolai Creek Unit #3 167‐007 Gas Prod 07/25/04 7/24/2004 1550 Y NA NANicolai Creek #9 202‐208 Gas Prod 09/27/06 9/23/2006 2000 Y NA NANicolai Creek Unit #10 210‐127 Gas Prod 05/25/13 5/21/2013 1500 Y 5/21/2013 1500 Y NA NANicolai Creek Unit #11 209‐067 Gas Prod 09/23/09 9/22/2009 3000 Y 9/22/2009 2000 Y NA NA • • OF T7 y� ) y�s THE STATE Alaska Oil and Gas ...fALAsKA Conservation Commission _ 333 West Seventh Avenue ,,..77177- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OSA Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock Manager Aurora Gas, LLC SCAN NE® JUL 1 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Nicolai Creek Field, Undefined Upper Tyonek Gas Pool,Nicolai Creek 3 Permit to Drill Number: 167-007 Sundry Number: 317-278 Dear Mr. Pollock: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. The Alaska Oil and Gas Conservation Commission(AOGCC)approves the setting of a temporary plug in this well to provide isolation from the reservoir as a short-term barrier. This work does not meet AOGCC's regulatory requirements for suspension or plugging and abandonment of this well. Prior to relinquishing the lease back to the landowner, the operator is required by law to properly plug and abandon this well. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this l day of July, 2017. RSDM►S JUL 1 1 2017 • • RECEIVE() STATE OF ALASKA JUN i ALASKA OIL AND GAS CONSERVATION COMMISSION 2017 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Weil ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other Temporary Plug Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Aurora Gas,LLC Exploratory ❑ Development El. 167-007 ' 3.Address: 1400 W.Benson Blvd.Suite 410 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-283-20003-00 , 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N) - Nicotai Creek#3 Will planned perforations require a spacing exception? Yes ❑ No 2' N..) 9.Property Designation(Lease Number): 10.Field/Pool(s): (t 'YhAkti- ADL-63279 ' Nicolai Creek North Undefined,pas Piq' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8841' 8841' 2319' 2319' 750 psi 2319' None Casing Length Size MD TVD Burst Collapse Structural Conductor 282' 20"85# 282' 282' Surface 2001' 13 3/8"54.5#J55 2001' 2001' 2730 psi 1130 psi Intermediate Production Liner 581' 7"29#N80 2522' 2522' 8160 psi 7020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1494'-2319' 4 1494'-2319' 23/8" 4.6##J55 1410' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker single set PIP and DB permanent seal bore packers ' Baker PIP @ 1410'and DB @ 1803" 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ ' Service ❑ 14.Estimated Date for TBD 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q " WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: George Pollock,. Contact Name: George Pollock Authorized Title: Manager- Ol.- .r Contact Email: 000ltock pc aurorapower.com �- Contact Phone: 907-277-1003 Authorized Signature: Date: 16-Jun-17 COMMISSION USE ONLY Conditions of approv. : Notify Commission so that a representative may witness Sundry Number 3t7- 2.-7F- Plug Integrityy ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: A` ‘ Y`Jv^_AsR�tC.vw,C'' Ft-US NW- 6•L-"t" iZ(.(.U.i12K,-Mir`NZS F Di.'., `S'v.SF�'Ni,,ttk-3 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 —4i3 A RBDMS JUL 112017 Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: 4 (L 1l'. G 1rm,a4eit /so/� AW7 ,m -,i-4i-1 1_ Rr1v6a1Pf41jhi 1 Subs i Form ane d for 12 months from the date of approval. Attachments in Duplicate • • Aurora Gas, LLC June 16, 2017 Ms. Cathy Foerster, Chair RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7t'Avenue, Suite 100 )NN 1 2017 Anchorage, AK 99501 II cc Re: Application for Sundry Approval—Set Temporary Plug Nicolai Creek#3 Well PTD #: 167-007 API #: 50-283-20003-00 Dear Ms. Foerster: Aurora Gas, LLC hereby requests approval to set a temporary plug to secure this onshore development well in the Nicolai Creek North Undefined Gas Field on the west side of Cook Inlet, southwest of the Village of Tyonek. This well is currently shut-in, is capable of producing gas from multiple zones in the upper Tyonek sands and is mechanically sound. Aurora Gas is currently in Chapter 11 bankruptcy protection while attempting to reorganize and emerge with new owners/investors. This application is being submitted as part of our Reorganization Plan filed with the bankruptcy court if liquidation actions are ordered. Aurora Gas, LLC will provide all potential new owners/investors notice of the impending action before on-site activity begins. The proposed work involves setting a plug via wireline in the profile at a depth of 1,376' above all open perforated intervals to mechanically isolate the reservoir. After the plug is set, tubing pressure will be monitored for 30 minutes to ensure isolation. The master valve will be closed providing double isolation and the wellhead secured. A follow up pressure reading will be obtained after 24 hours to ensure the integrity of the plug. Please find the attached information as required by 20 AAC 25.110 for your review: • Form 10-403 Sundry Application • Current wellbore diagram illustrating the current well configuration. • Slickline Temporary Plug Set—Generalized Procedure If you have any questions or require any further information, please contact me at(907) 277-1003. Sincerel y/7 eorge Pollock Manager—Production Operations &Engineering 4645 Sweetwater Boulevard,Suite 200 * Sugarland,TX 77479 * (832) 939-8991 1400 W Benson Blvd, Suite 410 *Anchorage,AK 99503 * (907) 277-1003 S Nicolai Creek Unit No. 3 2 3/8"4.6#8rd EUE Mod Prod Tbg to1424'w/3'A"pup jt — below tubing hanger at surface. NCU#3 * PTD# 167-007 '`` RKB 16' GL 246' Current Configuration c. :;- : 28-Aug-2004 ' Drilled 26"Hole Post 2004 Work-Over , 20"85#Conductor*282' and Completion '. Cemented Wi 720 Sks Cmt , Weatherford 1.87XA Profile r sliding sleeve @ 1376' ' ." I 1 Jt 2 3/8 tubing between ► '* sliding sleeve and PIP *� Baker Single Set PIP Packer a at 1410'set wi 20k-lb pull Baker X-Nipple w/1.87"Profile at 1 _. shear release. Production Perforations shot Ii e w/7"Halliburton TCP guns ', 4'/:"Weatherford Screen 1488'-1548' CO,12 spf and.36"holes. ••`o' f--" 1494'-1502' __�„� Install 2 3/8"tubing above and below 1506'-1512' —��■ 4'/:"screen 1516'-1542' ;. II 01 CS Baker BXN Nipple w/1.87 profile/ Baker Model DB Permanent '' IN1.791 NoGo installed at 1486' Seal-bore type production ' packer at 1803'MD r, •, 0.63"Bakerweld gravel pack screen. Production •Perforations: 47#9 5/8"Base Pipe from 1900-1931' 1900'-1930' i }, 2 3/8"4.6#8 Rd tubing hung off seal ► <---4- , ' 13 3/8"54.5#J-55 a 2001' assembly from 1809'-1872'&1.9" ` ;, ../,' Cemented w/1770 Sks 2.76#l ORd API IJ Blast Joint from *,.- Cmt. 1874'-1994'as velocity string inside "*;•", • '« of Bakerweld Screen. 4.25"Bakerweld gravel pack screen.9.2#3'/A"Base Pipe Pipe ID 2.992"from 1933'- 2346'(Bottom now cemented) Production Perforations: 2005'-2032'MD 2201'-2238'MD Figure I 2303'-2319'MD ' New PBTD TOC 2319'MD 4-- ---30 Note: For more detail.please see Figure x • II,attached Gravel Pack and Perfs % 2319'-2380'Squeezed off with cement in 2003 �,**r Well Gravel Packed with - .< 29,744 lbs of 12/20 sand from 1812'-2487'in 2000. • /_ , v• t#v **** * `. 7"29#N-80 Liner*2522'MD&TVD A . *...+• **. $I' r'' Cemented w/220 Sks Cmt. � ar Aurora Gas, LLC Page 7 of 7 S • AURORA GAS, LLC Slickline Temporary Plug Set - Generalized Procedure June 2017 SUMMARY: This procedure describes the steps taken to set a temporary plug in wells operated by Aurora Gas, LLC to secure the well for a short term shut in. RIH with drift for the appropriate sized tool for the tubing, in most cases 2 7/8"tubing with 2.312" or 3 %"tubing with 2.812"X landing nipple profile. Set PXX plug in uppermost landing profile. If a profile is not available, RIH with tubing stop pack-off plug and set above uppermost packer. After plug is set, a negative pressure test will be performed to ensure the plug has isolated the productive intervals from the surface. Upon passing the negative pressure test, the wellhead will be secured. PROCEDURE: 1) AG Operators to shut-in well and monitor pressure while rigging up. 2) RU Pollard Wire Line and lubricator on tree after removal of tree cap. Open well to pressure test lubricator—have pressure gauge on lubricator. 3) RIH with appropriate drift for X profile and sliding sleeves in upper profile. Pass through sleeve approximately 10' to insure safe operation of setting tool. POOH. 4) RIH with PXX Plug body on X-Line running tool. Set Plug body in upper most Sliding sleeve X profile above upper most production packer in well. 5) RIH with RB retrieval tool as running tool with prong. Set Prong in Plug body and POOH. 6) Record pressure and Bleed well bore to zero PSI, Monitor for 30 minutes recording pressure readings at 15 minute intervals. 7) Test successful if no pressure increase observed. If test fails, RIH and reset plug. 8) RDMO Pollard Wire Line. 9) Secure the wellhead. 10)Move to next well. 11)After 24 hours, a pressure reading will be obtained to ensure the integrity of the plug. .4,1e Sauafe(6/11/2017) I"'C t~ ~WŒI~Œ E & P SERVICES, INC. September 1, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED SEP -. 3 2004 Alaska Oil & Gal Cons. Commission Anchorage Re: Final well completion report and operations summary: Nicolai Creek Unit No.3 (PTD# 167-007) ",..,.. ~ .r¡' Dear Mr. Norman, On behalf of Aurora Gas, LLC, Fairweather E&P Services Inc., hereby submits the final well report which covers both the work-over and re-completion of Nicolai Creek Unit No.3. Operations were completed on July 24th, 2004. Pertinent information included under cover ofthis letter includes the following: 1) 2) 3) 4) Form 10-404 "Report of Sundry Well Operations" - 2 copies. Wellbore schematic Completion schematic(s) Summary of daily well work and operations. If you have any questions or require additional information, please contact the undersigned at (907)258-3446, or Mr. J. Edward Jones, Executive Vice President of Engineering and Operations for Aurora Gas, LLC at (907)277-1003. Sincerely, Fairweather E&P Services, Inc. ~~)~ Duane H. Vaagen . Project Engineer att: cc: J. Edward. Jones, Andy Clifford ORIGINAL 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Performed: Alter Casing 0 Change Approved Program 0 2. Operator Aurora Gas, LLC Name: Suspend U Repair Well 0 Pull Tubing 0 Operation Shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Perforate~ WaiverU Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: ExploratoryD 167-007 Service 0 6. API Number: 50-283-20003-00 9. Well Name and Number: Nicolai Creek Unit No.3 10. Field/Pool(s): Nicolai Creek Gas Field Other U 1400 West Benson Blvd, Suite 410 Anchorage, Alaska 99503 7. KB Elevation (ft): 16.5 ft AGL, 262 ft AMSL 8. Property Designation: ADL 63279 11. Present Well Condition Summary: 3. Address: Total Depth measured 8841 true vertical 8841 feet feet Plugs (measured) Junk (measured) Effective Depth measured 2319 true vertical 2319 feet feet Casing Structural Conductor 282' Surface 2001' Intermediate Production Liner 581' Length Size MD TVD Burst Collapse 20" 133/8" 282' 2001' 282' 2001' structural 2730 1130 7" 2522' 2522' 8160 7020 Perforation depth: Measured depth: New Perforations: 1494' -1502',1506' - 1512', 1516' -1542'. HOWCO 7" TCP guns, .36" holes at 12 spf. True Vertical depth: Same as above Packers and SSSV (type and measured depth) Baker PIP @ 1410' Baker DB at 1803' (See Attached Figure I and Figure II) --RECEIVED S£P - s 2004 Alaska Oil & Ga. Cons. Gommissio~ Anchorage Tubing: (size, grade, and measured depth) 23/8" 4.6# J-55 8rd EUE to 1410' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: RBDMS BFL SEP' 0 3 2004 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 0 0 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 460 Service 0 x GINJ 0 WINJ 0 WDSPL 0 ISUndry Number or NIA if C.O. Exempt: 304-125 Contact: J. Edward Jones, Executive VP Engineering and Operations Aurora Gas, LLC (#277-1003) Prepared By: Printed Name L:Z.I<-" //, ~.. Signature (À 1/ J -. ~.. E./.7".~& Form 1 0-404 Revis~03---> Title Project Engineer, Fairweather E&P Services, Inc. ORrGfNAL Date 2-Sep-04 WELL DRILLING AND COMPLETION REPORT NICOLAI CREEK UNIT NO.3 Shirleyville, Alaska ~~Aurora Gas, LLC 28 - August - 2004 Aurora Gas, LLC Page 1 of 7 Background Information: The Nicolai Creek Unit No.3, a natural gas production well was last re-entered and re- completed in August 2003. Repeated attempts at getting the well to flow commercially have since failed. Based new seismic interpretation and log analysis, a decision was made to perforate and test shallower Beluga sands located behind the 13 3/8" surface casing for potential pay. The following well work summary details the re-entry, treating and completion work chronologically. Dates indicated reflect date morning report(s) were received in office and reflect site activities over previous 24 hour period, i.e. 0700 hrs on day previous to 0700 hrs on date of report generation and submittal. Figure I, is a generalized schematic of the well as completed and Figure II is a detailed description of the actual hardware downhole at this time. Work Summary and Dailv Activities: 19-May-2004 Remove well house from well and begin mobilization of rig and ancillary equipment across Cook Inlet to well site via barge. 20-May-2004 Safety Meeting to discuss operations and begin prepping site by laying out Herculite ground liner, setting rig mats and start spotting rig equipment on location. hlstalllubricator and BPV prior to setting rig equipment near well. 21-May-2004 Rigging up. 22-May-2004 Rigging up. 23-May-2004 Rigging up. Raise derrick on rig, prep pits, test brine properties and prepare for cased hole work. 24-May-2004 Pull BPV, dump 10 bbls Calcium Carbonate / brine pill, pressure "0", well dead. RU slickline, pressure test lubricator and wire line valve - good. RllI w/ 2-3/8" BO shifting tool to 1749' KB. Beat up on sleeve, pull through, POOH, piQ. sheared in shifting tool. RllI w/ 2-3/8" BO shifting tool to 1749', shift sleeve open for well kill operations, POOH, pin good. Kill well by circulating around 60 bbls brine with check for flow, close in tree, RD, park equipment, go home. Missing BOP bolts, order out set. 25-May-2004 Set BPV, ND tree, NU BOPE. 26-May-2004 Continue NU BOPE. Weld up 2-3/8" test joint, weld on shakers and drilling nipple/flow line. RU and calibrate gas detectors. Cavity test stack, Hydril failed on low pressure test. Hydril tested. Pull up test joint, secure well with blind rams. Aurora Gas, LLC Page 2 of 7 27-May-2004 Test BOPE to 5000 psi. State rep witnessed and signed off. Pull 2 way check valve, release Cameron rep, secure well for night. 28-May-2004 Weld up flow nipple and flow line to shakers. NU flow nipple and flow line. Weld up hole in bottom of shakers. Set pipe racks, secure well for night. 29-May-2004 Fill hole. Took 32 barrels. Check for pressure - OK. Pull landing hanger and CBU while working on flow nipple. NU flow line. POOH wi 2-3/8" string, dress Baker bridge plug, pull up hole, dump 5 sacks sand, pull 3 stands, secure well bore. Checked plug wi 300 psi to assure it set. 30-May-2000 Check well for fill and pressure. POOH wi 2-3/8" string. RU for 3-112" drill pipe. Change ra.ms to 3-112". Test 3-112" rams. Rlli wi 3-112" d..-ill pipe. Tag sand @ 1804'. RU, break circulation for filtering. Filter hole volume to 10 microns. Cleaned up transmission spill. 31-May-2004 PU 7" HOWCO perforating guns. RIH to 1550'. RU slick line. RIH wi SDI logging tool to 1550', POOH, logging speed, standby for data download, no data. RIH wi logging tool to 1558', log, POOH wi logging tool. Data good. Standby for correlation and moving drill pipe up to shoot zone. RD slick line, RIH wi 2" blind box to 1477' KB. POOH, confirm depth of drop bar, guns did not fire. RD, release slick line unit. 1-June-2004 2-Jun-2004 3-Jun-2004 4-Jun-2004 Aurora Gas, LLC Hold JSA prior to pulling misfired guns. RU to POOH. Bad firing head, hot shot new head from Kenai. Checkout gun connection while waiting on head. Perforate 13 3/8" casing wi 7" HOWCO Millenium TCP guns at 12 spf and .36" holes. Well perforated at following intervals: 1494' - 1502', 1506' - 1512' and 1516' -1542'. Check for flow, well went on vacuum. POOH wi perforating guns, LD guns, release HOWCO. RIH wi 13-3/8" casing scraper to 1500'. SD for night. Finish trip in wi casing scraper. POOH wi scraper. PU Baker plug catcher, RIH. Tag sand by reverse circulating. Made 3', unable to latch in. CBU, monitor fill closely during trip. POOH, no plug - probably debris packed around mandrel. Pick up power swivel. SD for night. Check well for fluid and pressure. RU power swivel while waiting on Baker rep. PU overshot, RIH, space out, swivel up. Tag fish, wash over fish neck, PU and release Baker bridge plug - free at 65000# over string weight. POOH wi bridge plug; plug parted - slips and packer left in hole. Function test stack, HCR, PVT and gas detectors, fax results to state. PJSM - stage DC and handling equipment. Function test BOPE. PU fishing tools and drill collars. RIH wi singles drill pipe - PU power Page 3 of 7 5-Jun-2004 6-Jun-2004 7-Jun-2004 8-Jun-2004 9-Jun-2004 Aurora Gas, LLC swivel. Jar Baker bridge plug loose, circulate gas out of hole. LD 3-112" drill pipe and BHA wI fish. RU DP handling tools and power swivel. PJSM - ND flow nipple, run test plug. Change 3-112" rams to 2-3/8" rams. Test door seals to 3000 psi. Modify and install flow nipple. Rill wI completion - 1.9" blast pipe - 60' sand screens - 13-3/8" packer - 2-318" completion string. Space out and land completion. Clear tubing wI 10 barrel filtered brine. Attempt to set packer - unsuccessful. SD for night. PJSM. Attempt to set 13-3/8" retrievable packer - unsuccessful. Reverse 20 barrels to wash debris from packer. Attempt to set packer - would not set. LD hanger. POOH to inspect 13-318" packer. Slips dull and packed off wI debris. LD packer, WO replacement from Weatherford. Install test choke. MU packer, RIB wl2-3/8" completion. Ra.'1 four 4-3/4" collars above sliding sleeve for weight to set packer. Space out and land hanger, displace tubing wI filtered brine. Attempt to set packer, would not set, slips would take weight slacking off - slipped when picking up. POOH wI 2-3/8" completion. Attempt to set packer after pulling stand. Unsuccessful. POOH to inspect packer. SD for night. Wait on orders. Decision to run packer on drill pipe. WO 4-1/2 IF x 3-112 EVE sub (Need to cross over test plug so that screen assembly can be hung off and rams changed to 3-112"). MU test plug onto screen assembly, hang off screen assembly. On test plug, change rams to 3-112". Test rams to 3000 psi, LD test joint. MU screen assembly and 13-3/8" Weatherford packer wI eight 4-3/4" collars and run to setting depth of 1415'. Attempt to set packer on drill pipe - would not set. Slacked off 10' before bottom slips engaged. POOH wI 3-112" drill pipe. SD for night. PJSM. Test BOPE. Suspend test. Decision made to suspend operations and move to different well while locating alternative packer options. Prepare to suspend well while reviewing packer options. Rill wI 4-3/4" collars and 3-1/2" drill pipe. LD drill pipe and collars. MU test plug. Change rams to 2-3/8". Test to 3000 psi. LD test plug. Rill wI sand screen completion, sliding sleeve and 46 joints 2-3/8" tubing. MU hanger and land tubing. Commence tear down. (Decision made to set back pressure valve and start ND operations). PJSM. Start rig engine and light plant. Move pipe racks and catwalk for easy access to BOPE. Set BPV. ND BOPE. Stage tree in cellar, install tree on wellhead and NU. Pressure test hanger. Remove BPV and install TWC. Presssure test tree to 3000 psi. Pull TWC, install BPV. Tear down and move to Kaloa No.2. Rig Released @ 2900 6/9/04 until further notice. Page 4 of 7 10-Jun-2004 Tear down A WS No.1 and stage loads at Kaloa airstrip. Drive rig to Kaloa airstrip, haul mats to Kaloa No.2 site. Operations suspended until later date. RESUMPTION OF NCU #3 COMPLETIONS AND TESTING OPERATIONS: 18-Jul-2004 Move in A WS rig No 1. Raise derrick, set mud pit and generator. Set up rig floor. Assembled BOP system, set choke skid. 19-Jul-2004 Set stairs, floor pieces, super choke, flowline, mud shack, logging shack, hook up power on SW ACO choke. RU choke and lines kill well, monitor. Set BPV, RD tree, set BOP and Ru. 20-Jul-2004 RU BOPE and test. Repair I replace malfunctioning valves. Build 8.5 ppg brine in pits. Circulate around tubing wi returns to gas buster. Monitor well, prepare to POOH. 21-Jul-2004 22-Jul-2004 23-Jul-2004 Aurora Gas, LLC PJSM. Monitor well. POOH w 2-3/8" tubing. POOH wi sand screens and tailpipe. Change rams to 3-112". Test to 3000 psi. RIH wi Baker "S" plug and set in top of packer @ 1803'. Level rig, haul ten joints 3-112" tubing fÌom TCY. POOH wi 3-112" tubing. Wait on SDI to run caliper log. Up load caliper log. RIH wi WIL caliper log. RG WIL. MU 13-3/8" BHA wi Halliburton RTTS. RIH wi Halliburton RTTS to 500'. Attempt to test 13-318" casing w/RTTS tool. Packer would not seal. POOH to drill collars. WO collars fÌom Kaloa No.2. RIH wi Halliburton RTTS to 920'. Attempt to set RTTS @ 915'. Would not set. RIH to 880', would not set. POOH to 852', would not set. POOH to 790', RTTS set. Attempt to pressure test to 1000 psi, bled offto 50 psi in 10 min. Repeated wi same results. Bled off to 250 psi in 5 minutes POOH to 725', set RTTS, pressure test to 1000 psi. 10 min w no pressure loss. RIH to 758', pressure tested to 1000 psi. Leaked offto 250 psi in 10 min. Casing leak below 725'. Wait on orders. RIH to 1418' and establish leak-off. Pressure bled to 300 psi in 15 min and stabilized. RU to flow test open perfs fÌom 1404 to 1542'. Flow test well. SI well, RD swabbing lubricator. SI well and monitor pressure. Final pressure - 580 psi. Open circulating valve above packer, circulate and kill well wi 8.5 ppg fluid. During process of opening circulation valve, packer opened and gas migrated up annulus. RU and circulate long way. POOH wi 13-3/8" RTTS. PJSM. POOH and LD 13-3/8" RTTS. PU and Rill wi Baker plug puller. RU tubing swivel and wash down to plug. Wash and rotate over plug wi Page 5 of 7 24-Jul-2004 25-Jul-2004 26-Jul-2004 Aurora Gas, LLC overshot. PU to 20K over string weight. Pulled loose and returned to string weight. All indications show plug pulled out of packer. CBU gas bubbles to surface - maxed at 2300 units. Circulated thru Gas buster until gas circulated out. Monitored well, RD tubing swivel, POOH, retrieved Baker plug. LD Baker plug, retrieve tool and bumper sub. RIH wi 4-3/4" drill collars and 3-1/2" tubing and LD. RD tubing swivel, change out pipe handling equipment. Change out pipe rams from 3-1/2" to 2-3/8". Press test to 3000 psi. RU to run completion assembly. RIH wi completion assembly. Space out completion. MU hanger and land completion. Mix corrosion inhibitor and pump into place. PJSM, service rig. Pump corrosion inhibited brine in 13-3/8" x 2-3/8" annulus - 201 bbl. RU Pollard W/L and close sliding sleeve. RU to set packer. Pressured up to 750 psi and bled off (Leaking down hole - suspect that sliding sleeve not closing). RU WILand attempt to function sliding sleeve. RIH and confirm that plug is in X-nipple. (Pollard believes sliding sleeve closed.) Attempt to set packer wi test pump - would not pressure up. RIH wi W/L and retrieve plug from X-nipple. Inspect plug and RIH wi plug and reseat in X-nipple. RIH wi W/L and shift sleeve to fully open position and pump down tubing to wash any debris out of sliding sleeve. RIH wi WL and shift sleeve to closed position. Attempt to set packer wi test pump, would not set. Attempted to set wi rig pump - pressured up to 500 psi, bled off to 480 psi. Pressured up to 1000 psi and held for 5 min. Pressured to 1500 psi, bled offto 1450 psi. Pressured to 1600 psi, bled off to 1550 psi and stabilized. Called town to discuss. Proceeded to pull plug out of X-nipple and place in XN nipple. Run W/L (two runs). Fill tubing with water, lay down landing joint. ND 13-3/8" stack. NU tree and test to 5000 psi for 10 min. Good test. Broke tower at 0200. Night crew will return at 0700 to help day crew. Prep for swab, tear down rig. Swab in well. 9 swabs to bring on well. Flow back. Well pressured between 0 - 550 psi depending on choke settings. Did not want to unload water and flow @ expected rate. After flowing for 2-1/2 ills through ~lly opened choke wi less than 50 psi. Decision made to make swab run. Swab did not encounter any fluid level and reached sliding sleeve after resuming flow testing. No noticeable difference in water unloading. Drop 2 soap sticks to help stimulate water unloading. Unloading improved - continued to unload well. Took pressurelflow measurements as follows: 170 psi on 24/32 and 260 psi on 16/32. Bled off well. Bled off tree and dropped 2 sticks of soap. Shut in well for 15 min. FSIP 460 psi. Bled off and set BPV. RD A WS #1 and load up trailers. Move to Long Lake No.1 for re-entry work. Page 6017 NCU #3 PTD# 167-007 Current Configuration 28- Aug- 2004 Post 2004 Work-Over and Completion Weatherjord 1.87 XA Profile sliding sleeve@ 1376' 1 Jt 2 3/8 tubing between sliding sleeve and PIP Baker X-Nipple wI 1.87 "Profile at 1 Production Perlorations shot wI 7" Halliburton TCP guns @ 12 spfand .36" holes. 1494' -1502' 1506' -1512' 1516' -1542' Baker Model DB Permanent Seal-bore type production packer at 1803' MD Production Perlorations: 1900' -1930' 2 3/8" 4.6# 8 Rd tubing hung off seal assembly from 1809' -1872' & 1.9" 2.76# lORd API IJ Blast Joint from 1874' -1994' as velocity string inside of Bakerweld Screen. Production Perforations: 2005' - 2032' MD 2201' - 2238' MD 2303' - 2319' MD New PBTD TOC 2319' MD Gravel Pack and Perfs 2319' - 2380' Squeezed off with cement in 2003 Aurora Gas, LLC Nicolai Creek Unit No.3 23/8" 4.6# 8rd EVE Mod Prod Tbg to1424' w/3 Yz" pup jt below tubing hanger at surface. RKB 16' GL 246' Drilled 26" Hole 20" 85# Conductor @ 282' Cemented WI 720 SIcs Cmt Baker Single Set PIP Packer at 1410' set w/20k-lb pull shear release. 4 Yz" Weatherlord Screen 1488' - 1548' Install 2 3/8" tubing above and below 4 Yz" screen Baker BXN Nipple wI 1.87 profile I 1.791 NoGo installed at 1486' 0.63" Bakerweld gravel pack screen. 47# 95/8" Base Pipe from 1900-1931' 13 3/8" 54.5# J-55 @ 2001 ' Cemented wI 1770 SIcs Cmt. 4.25" Bakerweld gravel pack screen. 9.2# 3 Yz" Base Pipe Pipe ID 2.992" from 1933' - 2346' (Bottom now cemented) I Figure I Note: For more detail. "lease see Fit!ure II. attached. Well Gravel Packed with 29,7441bs of 12/20 sand from 1812' - 2487' in 2000. 7" 29# N-80 Liner @ 2522' MD & TVD Cemented wI 220 SIcs Cmt. Page 7 of 7 ,""""",,"',,-"""w.nc '......,NT__COCA""" """'DCA""" l'&ií8 ~ J Baker Oil Tools Baker 011 Tools BAKER 2 Kenal,Alaska 907- HUGHES Completions 776-8131 '"' Baker Oil Tools f""'ATOR 'AX- ... Aurora Gas,LLC ~..... """'" ""'DEV. "" DEV. Page: 1 Jack McDade REU> ""'-NO. """"'" 4.5 ,,"""""""- WEST SIDE NCU#3 16.47 7 ATE ....... ........ COWI.E""""'-"'-""'" co......""" Alaska Nicolai Creek brine I""-' DOCK """"- .......T1CN8 ..... """"- CASING 133/8 54.50 L-80 Aurora Well Servo """""." """'" LINER D.P. Byrd Sr. 907-776-8131 TE.....,... ""'-_. TUBING 2-3/8 4.60 C-90 EU 8rd 26-Jul-O4 ........... ""'- m< WRKSTR. Gas No. DEPTH LENGTH 00 10 DESCRIPTION 1 16.47 RKB 2 0.62 Cameron Tubing Hanger 3 17.09 1.70 3.500 2.992 31/2 EUE Tubing Pup 4 18.79 0.75 4.540 1.995 3 1/2 EUE X 2 3/8 EUE XO 5 19.54 18.10 2.375 1.995 23/8-4.6# Pup Jts.(6.06-6.00-6.04) 6 37.64 1338.74 2.375 1.995 23/8-4.6# (42 Jts. Tubing) 7 1376.38 2.43 3.050 1.870 Weatherford Sliding Sleeve (1.87 XA Profile) 8 1378.81 31.24 2.375 1.995 23/8-4.6# (1 Jt. Tubing) 9 9 1410.05 14.29 10.375 2.680 Baker Single Set PIP Packer(20,OOO# Pull Shear Release) 10 1424.34 61.71 2.375 1.995 2 3/8-4.6# (2 Jts. Tubing) 11 1486.05 1.15 2.730 1.870 X-Nipple (1.87 Profile)2 3/8 EUE 12 1487.20 1.05 4.500 2.000 41/2 LTC X 2 3/8 EUE XO 13 1488.25 30.10 5.120 4.125 4 1/2 Weatherford Screen 14 1518.35 30.10 5.120 4.125 4 1/2 Weatherford Screen 15 1548.45 1.89 5.063 2.950 23/8 EUE X41/2 LTC XO 16 1550.34 218.91 2.375 1.995 2 3/8-4.6# (7 Jts. Tubing) 17 1769.25 1.05 3.060 1.791 BakerBXN Nipple 1.87 profllel 1.791 No Go 18 1770.30 31.60 2.375 1.995 23/8-4.6# (1 Jt. Tubing) 19 1801.90 7.12 4.750 3.000 190-47 Locator seal assy(Locator 1.50 OFF PACKER TOP) 20 1809.02 62.64 2.375 1.995 23/8-4.6# (2 Jts. Tubing) 21 1871.66 2.57 2.400 1.500 2 3/8 eue x 1.900 Blast joint 11 22 1874.23 120.50 1.900 1.500 1.900 Blast Pipe (6 joints) 23 1994.73 Bottom Blast Joints ¡ 13 14 r:::....... ......... II I IMYI '" I I 17 19 22 NOTE: Top of DB Packer set al 1803' Localor 1.5 'offlop of packer/Inflatable packer shear release set 81 20,000# Re: Final \Veekly Repon--Kaloa #~ t... . .'~ d-? Subject: Re: Final \Veekly Report--~ '-,-. '--- ~ From: Thomas l\.'aunder <tom_nlaunder@:'admin.state.ak.us> Date: 'Ned, 21 J ul 2004 07 :-1-4:36 -0800 To: Ed Jones <jejones@'aurorapower.conl> CC: Duane Vaagen <duanec?þfairweather.com> \(cl:-\~~(~~ Ed, Thanks for the information. With regard to NicolaI Crk #3. The last IIpaperwork" is show was a 403 for the operational SD. I checked the sundry and all that was required was notice to resume operations. I would appreciate If Duane could send an email, maybe added to the last we exchanged on #3, with some Information on the resumption of operations. I presume that you now have the equipment rebuilt/purchased that force the SD in June. Tom Maunder, PE AOGCC Ed Jones wrote: Tom, Attached is the final weekly report for the Kaloa #2 well. The well was briefly tested, the completion assembly run, and the rig was released on 7/15/04. We have rigged back onto Nicolai Creek #3 to finish the workover there (test the casing, test new perfs, and run completion assembly if successful). Please let me know if you have any questions or need more info. R.egards, Ed J. Ed Jones Vice President Engineering & Operations Þ.urora Gas, LLC I of I 7/21/2004 3:09 PM Re: F\\': Operational Shut down Sundry--N icolai Crk 1:/3--( 167-007'1 Subject: Re: F\V: Operational Shut down Sundry--Nico1ai Crk #3--( 167-007) From: Thomas I\'launder <tom_maunder@.ladmin.state.ak.us> Date: \Ved, 21 Jul 2004 15:09: 11 -0800 To: Bi11 Penrose <bill@:fairweather.com> CC: jejones@:~aurorapower.conl. duane vaagen <duane@fair\\'eather.co111> 8111, You recollection of the details is correct. This message will fill the need regardIng the IInotificationll requirement contained on the appro'led sundry. The requirements and specifications of that approval still apply to the new work. I trust that Aurora made notification to the Inspectors for an opportunity to wItness the BOP test. As Aurora proceeds with work on this well and others, the Inspectors should be notlfled of all BOP and diverter testing opportunities. Please also take note that the BOP testing inter:al for Þ.urora I s operat ions is II... not to exceed 7 days. II Depending on the operatlons, extensions beyond 7 days may be possible however Aurora's representative must make contact with the Commission's engineer or the Inspectors prior to the 7 day perIod expiring. Good luck with the work. Please call with any questions. Tom Maunder, PE AOGCC Bill Penrose wrote: Tom, Ed Jones and Duane Vaagen are currently on the West Side and out of e-mail contact so I'm writing to inform you of the resumption of operations at Aurora Gas' NCU #3. Recall that Aurora Gas applied for an Operational Shutdown status for the well via the attached documents and the Commission granted it. The well was shut down because the production packer would not set in it during the earlier attempt to complete it. A different packer has been obtained and casing evaluation tools mobilized to the well site. The rig has moved over the well and the BOPs have been nippled up and tested. A casing caliper log has been run and IS currently being evaluated. The plan forward is to test a shallower, potentially gas-bearing sand and, if encouraging, add it to the existing produclng intervals in this well, all per the work plan originally submitted. Re'3ards, Bill I of I 7/21/2004 3:09 PM ~ ~ ~ Aurora Gas, LI-C www.aurorapower.com 1400 West Benson, Suite 410, Anchorage, Alaska 99503 June 7, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval for Operational Shut-dovRECE\VED Nicolai Creek Unit No. 3 (PTD#e-~~mJ7j JUN 0 71004 Dear Mr. Norman, 0"\ & Gas Cons. commission A\aska I Anchorage Aurora Gas, LLC hereby submits an Application for Sundry Approval to temporarily suspend work-over operations on the Nicolai Creek Unit No.3 well. After recently perforating the well, Aurora was unable to install the completion in the well's 13 3/8" casing due to mechanical issues with the packers. Aurora would like to temporarily suspend operations until such time that suitable replacement packers can be located and shipped to Alaska. Aurora proposes to leave the well with tubing hung off in the well for a kill string, the well filled with kill weight brine and the wellhead installed. Please see Attachment I for information on the proposed temporary suspension. Aurora intends to return and finish completion operations on the well this summer as soon as is practically possible. Pertinent information attached to this application includes the following: 1) 2) Form 10-403 Sundry Application - Original and 1 copy Proposed wellbore schematic If you have any questions or require additional information, please contact the undersigned at (907) 277-1003 or Duane Vaagen at (907) 258-3446. Sincerely, ~ J dward Jones Executive Vice President, Operations and Engineering enclosures cc: Duane Vaagen (Fairweather E&P Services Inc.) nf""\1^!"'" , 10333 Richmond Avenue, Suite 710 . Houston, Texas 77042. (713) 977-5799 . Fax (713) 977-1347 1oo!) West 3rd Avenue, Suite £20 . Anchorage, Alaska 99501 . (907) 277-1003 . Fax (907) 277-1006 ~ STATE OF ALASKA ,....-..., ALA A OIL AND GAS CONSERVATION COM"'. -,SION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown l:d Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Suspend U Repair well 0 Pull Tubing 0 1. Type of Request: Aurora Gas, LLC 1400 West Benson Blvd, Suite 410 Anchorage, AK 99503 7. KB Elevation (ft): 3. Address: 262' 8. Property Designation: ADL 63279 11. Total Depth MD (ft): 8841' Casing Structural Ð?::r 6 ref /~ f RECE'VED~{~ JUN 0 7 7_004 Perforate U ~f%e~" ctrrr.u~Ml~§!idnJ Stimulate 0 -A\u~M1!¡i1Sh Other 0 d Drage Re-enter Suspended Well' 5. Permit to Drill Number: Exploratory 0 Service 0 167-007 6. API Number: 50-283-20003-00 9. Well Name and Number. Nicolai Creek Unit No.3 10. FieldlPools(s): Nicolai Creek ITotal Depth TVD (ft): 8841' Length PRESENT WELL CONDmON SUMMARY IEffective Depth MD (ft): ¡Effective Depth TVD (ft): 2319' 2319' Size MD TVD ¡Junk (measured): NIA Collapse Conductor Surface 264' 1985' 20"85# 13.375" 54.5# J-55 Intermediate Production Liner ¡Plugs (measured): CMT 2319' - 2522' Burst 282' 2001 282' 2001' 2730 psi 1130 psi 581 ' 7" 29# N-80 2522' perforation Depth TVD (ft): TUbing Size: 2005' - 2319' 23/8" Operational Shut-down 61712004 16. Verbal Approval: 1/ r'\ Date: ~ h -ö4 \ <0 '. '-\. Ù Commission Representative: ~<rrvt ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed~a J. Ed ífI J C- h ~ J Title Signature [~ Phone 713-977-5799 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Perforation Depth MD (ft): 2005'-2319', 1494'-1542' Packers and SSSV Type: Baker Model DB Permanent Sealbore I No SSSV 12. Attachments: Description Summary of Proposal l:d Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 2522' TUbing Grade: 4.6# J-55 Packers and SSSV MD (ft): Top of packer at 1803' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 Plugged WAG 0 GINJ 0 WINJ 8160 psi 7020 psi TUbing MD (ft): 1803' Well P&A'd: No 0 Service 0 0 Abandoned 0 0 WDSPL 0 Contact Mr. J. Edward Jones Executive VP Operations I Engineering Date ~/7ICJ</ Sundry Number: .3 tJ ~- ~/ 7 ¡.../' 0 Location Clearance 0 Other. "('0\--;\.'1 c...~~",,\~~,~~ ~\\(~,.~ ~5\,j't"\.\ I~ ô~~\-\.~~~ "-\ "' \ <Q\?q..\""\-ßI~ 1i9t1tð:t à ~ "',~ ~<,J" \s-.dÐ 0 't BY ORDER OF L~æ tJry CO..M..IM.IISS. ION... E. R. .. .. THE COMMISSION Date: lP JNSTRUCT'ONR ON RFVJ;;~SE Sub. in tpliCAt jUM 0 8 1nn~ (Ø)MS BfL ~ ,-....., ~\CD\~\ (\~ ~ ~ lGJ'ì -()()\ Tubing will be hung off with tubing hanger, backpressure valve will be installed and wellhead will be installed. ,. . ~?~ . ."'1t. I I ! f . ~ ~ , , ! ; ì \: ' '~. . " ~ 1 , j f i I ; { ¡ ! .~ ~ 4 ~ Ke: Aurora lias I NIcolaI Creek No.:> ,,-..... ~. Subject: Re: Aurora Gas / Nicolai Creek No.3 From: Thomas Maunder <tom- maunder@admin.state.ak.us> Date: Mon, 07 Jun 200416:42:00 -0800 To: duane vaagen <duane@fairweather.com> Duane, Your proposal to SD operations on Nicolai Creek #3 pending the receipt or rebuild of the packers is acceptable. The well is filled with kill weight fluid and you will be rerunning the tubing as a kill string. Please make sure that there are pressure gages on the annulus so that surface pressures may be observed/checked. Tom Maunder, PE AOGCC duane vaagen wrote: Tom: Per our phone conversation this morning, a Sundry Application requesting permission to proceed with an operational shut-down of work-over operations on the Nicolai Creek No.3 well should be headed your way from Aurora's office. Aurora intends to leave the well with a tubing kill string installed, wellbore full of kill weight brine (8.5+ ppg) , a backpressure valve installed and the wellhead installed. The intent is to move the rig off to begin drilling operations at the Kaloa No.2 well. In the interim, we are trying to locate an acceptable 13 3/8" replacement production packer to finish the completion operations on the NCU 3 well at a later date. At this time, no vendor in Alaska has 13 3/8" production packers in Alaska, and most of the US for that matter, so we may need to have one built up to replace the ones we had shipped in initially which failed to function properly. Regards, Duane Vaagen project Engineer Fairweather E&P Services, Inc. duane@fairweather.com <mailto:duane@fairweather.com> Office: (907)258-3446 Cell: (907) 240-1107 10fl 6/8/2004 6:40 AM ~Aurora Gas, LLC www.aurorapower.com April 16,2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval to Perform Workover Operations Nicolai Creek Unit No.3 (PTD# 167-007) Dear Mr. Norman: Aurora Gas, LLC hereby submits an Application for Sundry Approval to re-enter and perform work-over procedures on Nicolai Creek Unit No.3. Anticipated start date for this work is May 1, 2004. The rig "Aurora Well Service Rig 1" and ancillary support equipment will be used for the procedure. Rig configuration and BOPE will be the same as on previous Aurora projects. Aurora intends to pull the tubing and introduce new perforations to access potential pay behind the 13 3/8" casing from ~ 1494 - 1542 feet. After testing operations, the well will be re-completed based on test results to take advantage of the new pay intervals. Nicolai Creek Unit No.3 was last worked on in August of 2003 when a procedure was undertaken to mitigate a water production problem and low productivity. While it appears the water problem has been overcome, production has been disappointing. Aurora hopes to return the property to commercially viable production by undertaking the proposed work. Pertinent information attached to this application includes the following: 1) 2) 3) Form 10-403 Sundry Application - Original and 1 copy Proposed wellbore schematic Summary of proposed operations RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage 10333 Richmond Avenue, Suite 710. Houston, Texas 77042. (713) 977-5799 . Fax (713) 977-1347 1400 West Benson Blvd., Suite 410. Anchorage, Alaska 99503. (907) 277-1003 . Fax (907) 277-1006 If you have any questions or require additional information, please contact the undersigned at (713)977-5799, or Duane Vaagen at (907)258-3446. Sincerely, AURORA GAS, LLC :t~ J. Edward Jones Executive Vice President, Operations and Engineering enclosures cc: Duane Vaagen (FairweatherE&P Services Inc.) Andy Clifford (Aurora Gas, LLC) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Suspend U Repairwell 0 Pull TubIng 0 1. Type of ~equest: 3. Address: Aurora Gas, LLC 1400 West Benson Blvd, Suite 410 Anchorage, AK 99S03 7. KB Elevation (ft): 262' 8. Property Designation: ADL 63279 11. Tota! Depth MD (ft): 8841' k Y-(\ <-~ Development Stratigraphic 0 0 Perforate W Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: / Exploratory 0 167-007 V Service 0 6. API Number: -/ SO-283-20003-00 Annular Dlspos. U Other 0 9. Well Name and Number: Nicolai Creek Unit No.3 10. Field/Pools(s): Nicolai Creek Total Depth TVO (ft): 8841' PRESENT WELL CONDITION SUMMARY ¡Effective Depth MD (ft): ¡Effective Depth TVO (ft): 2319' 2319' Size MD TVD Junk (measured): N/A Collapse Casing Structural Conductor Length 264' 1985' 20~85# 13.375" 54.5# J-55 Surface Intermediate Production Liner Plugs (measured): CMT 2319' - 2522' Burst 282' 2001 282' 2001' 2730 psi 1130 psi Perforation Depth MD (ft): 200S' - 2319' 581' 7" 29# N-80 2522' ¡Perforation Depth TVD (ft): ¡TubIng Size: 200S' - 2319' 23/8" 8160 psI 7020 psi TUbing MD (ft): 1803' Well P&A'd: No CommissIon Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Na rdWard JO~ Tit!e 1/b-û11'~ ~dhone 713-977-5799 .. COMMISSION USE ONLY Conditi s of approvat: Notify Commission so that a representative may witness Packers and SSSV Type: Baker Mode! DB Permanent Sea/bore f No SSSV 12. Attachments: Description Summary of Proposal W Detailed OperatIons Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 5/1/2004 Date: Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 2522' ¡Tubing Grade: 4.6# J-SS Packers and SSSV MD (ft): Top of packer at 1803' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: on 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 ServIce 0 Abandoned WDSPL 0 0 Contact Executive VP OperatIons f Engineering Date 0/1::1 ßý Sundry Number: 3o4-IJ-S- v 0 Location Clearance 0 Other: '1 '\:)0 0 ~ ~ \ ~'" \. ~ ~,,~ ~ C) '? -\-Q::S* RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission ~nCh::~ 14 d ~it':fuDI~cle APR 2 1 ~r"\4 BY ORDER OF COMMISSIONER THE COMMISSION INSTRUCTIONS QIIfREVERSE ORIGINAL _Bfl Nicolai Creek Unit No.3 Nicolai Creek Unit No.3 is a gas producer currently on production. The well was worked on during the summer 2003 program when diagnostics were run to detennine the zone(s) of water influx which had gradually increased to the point where gas deliverability was zero due to well flooding out. Procedures were undertaken to treat and shut off the water. The well has produced intermittently since with poor deliverability likely due to damage of current production zone. / ~ The plan is to kill the well, pull the tubing completion, run wireline logs and perforate the casing at select shallower intervals using tubing conveyed guns. The new completion to be run will allow us to stab into the current permanent production packer's seal assembly and will include a new retrievable type packer and sand exclusion type screens. This will allow ability to either isolate deeper production or commingle with production from new shallow perforations. Procedure Summary: 1) Open sliding sleeve and circulate 3% KCI brine wI addition ofCaCO3 LCM as needed to prevent fluid loss to fonnation and speed kill operations. We need to be careful so we do not plug the original gravel pack screen currently in place. 2) Pull 2 3/8" tubing wi seal assembly 3) Rill with and set a 13 3/8" retrievable bridge plug just above the production packer currently in place and dump 5 sacks sand on top. 4) PU and RllI wI 7" tubing conveyed perforating gun and 3 W' tubing to depth. 5) RllI wI slickline to correlate depth of guns. 6) Perforate from 1494' -1502', 1506' -1512' and from 1516' -1542' wi 6 spf. Record surface pressure immediately after perforating and kill well by circulating KCI I NaCI through tubing and guns. 7) 8) RllI wi 13 3/8" casing scraper RllI wI plug retrieval tool, wash! circulate out sand and perforating debris, latch onto and pull retrievable bridge plug. 9) Run new completion wi retrievable type packer and sand exclusion type screens across all perforated intervals. 10) Displace packer fluid and upper annulus freeze protect diesel. Aurora NCU #3 2004 Workover Rev. 1.0 Page 1 of2 11) Install production tree, displace packer fluid, run and set X-profile plug in profile located at 1770'. Swab in well and flow test new perforations. 12) 13) Pull X-nipple and re-test well. 14) Put well back on production. Proposed Work Start Date: Well work is tentatively scheduled to start May 1, 2004. Duration of activities estimated at 5 - 8 days. Rig Information: The rig "Aurora Well Service Rig No. I" and ancillary support equipment will be used. Rig configuration and BOP equipment will be the same as on previous work Aurora has undertaken on its gas properties on the NW side of Cook Inlet. Aurora NCU #3 2004 Workover Rev. 1.0 Page 2 of2 Nicolai Creek Unit No.3 Current Configuration Baker Model CMU sliding sleeve @ 1803'w/l.81 X landing profile. Requires "B" Shifting tool. Baker Model DB Permanent Seal-bore type production packeratl803'NUD 23/8" 4.6# 8 Rd tubing hung off seal assembly from 1793' -1853' wi 1.9" 2.76# lORd API IJ Blast Joint from 1853' - 2289' as velocity string inside of Bakerweld Screen. Production Perforations: 2005' - 2032' MD 2201' - 2238' NUD 2303' - 2319' NUD New PBTD TOC 2319' NUD Gravel Pack and Perfs 2319' - 2380' Squeezed off with cement in 2003 23/8" 4.6# 8rd EUE Mod Prod Tbg to 1803' Aurora Gas NCU #3 Workover Drawing Not to Scale RKB 16' GL 246' Drilled 26" Hole 20" 85# Conductor @ 282' Cemented wino Sks Cmt 10.63" Bakerweld gravel pack screen. 47# 9 5/8" Base Pipe from 1900 -1931' 13 3/8" 54.5# J-55 @ 2001' Cemented wi 1770 Sks Cmt. 4.25" Bakerweld gravel pack screen. 9.2# 3 y." Base Pipe Pipe ID 2.992" from 1933'- 2346' (Bottom now cemented) Well Gravel Packed with 29,744 Ibs of 12/20 sand from 1812' - 2487' in 2000. 7" 29# N-80 Liner @ 2522' MD & TVD Cemented wi 220 Sks Cmt. Rev. 2, DHV Nicolai Creek Unit No.3 Proposed Configuration Re-install Baker Model CMU sliding sleeve @-1390'w/ 1.81 X landing profile. Requires "B" Shifting tool. New Production Perforations: 1494' - 1502' 1506' - 1512' 1516' - 1542' Baker Model DB Permanent Seal-bore type production packer at 1803' MD Production Perforations: 1900' - 1930' 2 3/8" 4.6# 8 Rd tubing hung off seal assembly from 1793' -1853' wI 1.9" 2.76# lORd API IJ Blast Joint from 1853' - 2020' as velocity string inside of Bakerweld Screen. Production Perforations: 2005' - 2032' MD 2201' - 2238' MD 2303' - 2319' MD New PBTD TOC 2319' MD Gravel Pack and Perfs 2319' - 2380' Squeezed off with cement in 2003 2318" 4.6# 8rd EUE Mod Prod Tbg to1425' RKB 16' GL 246' Aurora Gas NCD #3 Workover Drawing Not to Scale Drilled 26" Hole 20" 85# Conductor @ 282' Cemented WI 720 Sks Cmt New 13 318" Retrievable roduction Packer (Tension Set?) Set at -1425' Sand Exclusion Screen w/4 W' base pipe and cross-overs. 1496' - 1546' Install 2 3/8" tubing above and below 4 \1:" screen 1.81" X-Profile Nipple at-1770' to isolate lower perforations and production. 10.63" Bakerweld gravel pack screen. 47# 9 5/8" Base Pipe from 1900 - 1931' 13 3/8" 54.5# J-55 @ 2001' Cemented wI 1770 Sks Cmf. 4.25" Bakerweld gravel pack screen. 9.2# 3 \1:" Base Pipe Pipe ID 2.992" from 1933' - 2346' (Bottom now cemented) Well Gravel Packed with 29,7441bs of 12120 sand from 1812' - 2487' in 2000. 7" 29# N-80 Liner @ 2522' MD & TVD Cemented wI 220 Sks Cmt. Rev. 2, DHV ~~.;§Aurora Gas, LLC www.aurorapower.com January 5, 2004 Mr. Tom Maunder PE Senior Drilling Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Ste 100 Anchorage, Alaska 99501 RE: Sundry Report of Well Operatìons: Nicolai Creek Unit No.3 (167-007) Dear Mr. Maunder: Aurora Gas, LLC hereby submits the Report of Sundry Well Operations, which covers the tubing replacement, cement squeeze of lower perfs, and stimulation of Nicolai Creek Unit No.3. ~~Rig'~ operations were completed on November 17,2003 (i.e., wire line unit released), but we continued to blow down and test to recover load water, recommencing gas sales on November 21 s1. Pertinent information included under cover of this letter includes the following: 1) 2) 3) Form 10-404 ~'Report of Sundry Well Operations"-in duplicate; Summary of well operations; and W ellbore schematics depicting final well completion configuration. If you have any questions or require additional information, please contact the undersigned at (713) 977-5799, or Duane Vaagen at (907) 258-3446. Sincerely, Au ora Gas, LLC J. dward. Jones xecutive Vice Preside, Engineering & Operations '\ RECEIVED JAN () 9 2004 Alaska Oil & G as Cons C . Anchorage' ornrmssiolJ Att: cc: Duane Vaagen (:;;,("" '\j;",i"è'),i1a:;[;" \':))i:l'¡!!""J'..".d\"!:i¡';;i¡,r.::> . '..,h '", ~h 'J~.-,"'" .-;, ,! 1')[: ("....: OR\G\NAL 10333 Richmond Avenue, Suite 710. Houston, Texas 77042. (713) 977-5799 . Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220. Anchorage, Alaska 99501. (907) 277-1003. Fax (907) 277-1006 2, Name of Operator Aurora Gas, LLC 3, Address 1400 W, Benson Blvd, Suite 410 Anchorage, Alaska 99503 4, Location of well at surface 3369' FSL, 1668' FWL, Sec, 20, T11N, R12W, SM At top of productive interval @ 1900' MD 3366' FSL, 1662' FWL, Sec, 20, T11N, R12W, SM At effective depth @ PBTD 2319' MD & TVD) 3363' FSL, 1660' FWL, Sec. 20, T11N, R12W, SM At total depth @ 8841' 3035' FSL, 1290' FWL, Sec20, T11N, R12W, SM 12, Present well condition summary Total depth: measured true vertical 1, Operations performed: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: STATE OF ALASKA ALASKA Ot-\ND GAS CONSERVATION C ,1MISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown: Pull tubing: X Stimulate: x Alter casing: Plugging: - Repair well: X 5. Type of Well: Development: ~ Exploratory: Stratigraphic: Service: Perforate: Other: Squeeze Cement 6. Datum elevation (OF or KB) 262' KB above MSL 7, Unit or P(operty name Nicolai Creek Unit 8. Well number Nicolai Creek Unit No.3 9, Permit number/approval number 167-007 / 303-175 10. API number 50- 283-20003-00 11, Field/Pool Nicolai Creek 8,841 feet 8,841 feet Plugs (measured) measured 2,319 feet true vertical 2,319 feet Length Size 264' 20" 1985' 13-3/8" Junk (measured) Cemented Measured depth True vertical depth 720 sx 282' 282' 1770 sx 2001' 2001' 581' measured 7" 220 sx 1941' - 2522' 1900' -1930',2005' - 2032',2201' - 2238',2302' - 2319' 1941' - 2522' true vertical Same Tubing (size, grade, and measured depth) R r::: ~ ~ 23/8" 4.6# 8rd EUE Surface to 1853', then 1.9" 10rd APIIJ 1853' - 2289', Tbg from 1803' - 2289 hung off seal ~JNIt'lJIr/a~ED Packers and SSSV (type and measured depth) J Baker Model DB Packer set at 1803' w/ Seal-bore assembly, AN 0 13. Stimulation or cement squeeze summary ¡"ka Q'I Isolated and squeezed off lower gravel pack completion and perforated intervals from 2319' - 2380' with 6,5 bbls "G" ceh,§iJas Cons, Co " Intervals treated (measured) Anchora mmlSSlon Treated Perforated intervals from 1900' - 2319' ge Treatment description including volumes used and final pressure Perforated intervals treated w/1 01 bbls 25% methanol treatment followed by injecting 23,000 scf Nitrogen for clean up. 14. Representative Daily Average Production or Injection Data Oil-BBL Gas-Mct Water-Bbl Casing Pressure Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Prior to well operation Signed' J. rm 10-404 Rev 06/15/88 Tubing Pressure 7/31/03 390 48 0 0 250 12/9/03 0 330 15 16, Status ot well classification as: 210 0 Suspended: Service: Bfl JAM! 20~\ Title: VP Operations and Engineering 5/ó1 Date: OR\G\NAL SUBMIT IN DUPLICATE WELL WORKOVER REPORT NICOLAI CREEK UNIT NO.3 Shirleyville, Alaska ::,\ i,' i;'~~;i~,l').+ ~r~~J:";?t: ~¡,.:. ,; ," ,I~~ ¡J,'1 "'i:"'f>,I) ~'" ~~:".. i'~iI , , ,;;-"';i,~':; ~"!:~ A"";'~" ""'~" ¡¡Or" ~,., "'.,"b,,,'¡ "'~1'" 'I';"'" :'1""'" ~"!'~"""",~. 'i,¡: ,..<¡ .' ",:" -..,,', .,,",. "..."". ," 'f# " "" " .. ','", ,,' 5-J anuary-2004 A urora Gas, LLC Page 1 of 6 Background Information: The Nicolai Creek Unit No.3, a natural gas production well was last re-entered and re- completed in Decelnber of 2000. A decision was made to work on the well when in it was no longer econonlically viable to operate due to diminished production coupied with substantial water production. Based on a review of the production history, pressure build up and flow data, and analysis of a spinner log run, it was detennined that the perforated zone fron1 2360' - 2380' was the primary source of water influx. It was inferred from the analysis that this influx was likely contributing to the flooding of shallower zones, ultimately "drowning" the well when shut in. A program was developed where an attempt was made to shut off the water producing zone through placement of a cement plug and treat the shallower zones to remove the water blockage. The following well work summary details the re-entry, treating and completion work chronologically. Figure I is a schematic of the well as completed and Figure II is a tally and diagram of the final completion configuration in the well at this time. Work Summary and Daily Activities: 01-Aug-2003 Hold introductory and planning meeting in Anchorage wi all vendors and contractors. Begin rig mobilization operations in afternoon. Rig Aurora Well Service No.1 is being shipped from aSK dock via Red Dog barge to Tyonek for transport to well site. 02-Aug-2003 Mobilizing rig. Place felt and pit liner down for containment and begin spotting rig components on site. 03-Aug-2003 Mobilizing rig and rigging up. 04-Aug-2003 Rigging up, work on valves, and electrical. Continue mobilization of equipment to site. 05-Aug-2003 Rigging up. Welding up flow lines, set gas buster and RU PVT and gas detection systems. Mix 60 bbls 3% KCI in preparation for well operations. Had problems with mix hopper, had to modify with welder. 06-Aug-2003 Rigging up. Tie in choke line to gas buster. Finish hook-up of kill line. Kill well using bullhead method. Pumped 30 bbls 3% KCl. Initial injection pressure 750 psig. Well dead with 30 bbls displaced. Install back pressure valve and nipple down wellhead. Install 13 3/8" 5M double gate rams, close rams and secure well for night. 07-Aug-2003 Discovered 150 psig on well upon arrival at site. Continue rig up, set annular preventer and function test. Screw into top of tubing Aurora Gas, LLC Page 2 of6 08-Aug-2003 09-Aug-2003 10-Aug-2003 hanger and Bleed off and pump 50 bbls 3% KCl to kill. Continuing with floor and miscellaneous rig up. Continue with rig up of floor, set pipe racks and strap work string. Well again showing pressure. Attempt to bleed down but too n1uch volume. Pump another 50 bbls 30/0 KCl to kill well. Well went on vacuum, static with no pressure for 10 minutes then pressure building. Shut in well. Finalize all connections and prep for BOP test on following day. Continue rig up. During bundle test on stack, found one valve on choke manifold upstream of manual choke leaking. HCR on choke line also leaking. Work on repair and replacement of faulty valves. Notify AOGCC rep. Jeff Jones for following day to witness BOPE test. Test BOPE with Jeff Jones, AOGCC witness. Failed BOPE test with recovery time of 6 - 10 min. on accumulator. Other problems encountered included fluid leakage on (2) manual valves on choke manifold, (1) HCR leaking, (1) gas detector failure and problems with PVT system. AOGCC witness sent back to town until repairs l11ade. II-Aug-2003 Repair valves and deficiencies found on BOPE test of previous day. Locate and order out replacement Koomey unit of sufficient volul11e to adequately operate 13 5/8" 5M BOP stack. 12-Aug-2003 13-Aug-2003 14-Aug-2003 Aurora Gas, LLC Spotting tanks and fluids for well treatment program. Replacement Koomey unit arrived on barge. Haul to site and spot on location. Rig up test. Recovery time acceptable at 3 min. 45 seconds. Tested floor valves and TIW failed. Order out replacement and replacement manual valve for choke line. Replace 2" 5M valve on choke manifold. Test PVT and gas detection system and prepare for witnessed koomey recovery test as well as function ofPVT and gas detection systems. Jeff Jones wi AOGCC on location to witness test. Secure well for night. Finish BOPE test. Unlock and unseat tubing hanger, wouldn't clear flow nipple on stack. Re-set, strip off riser and again unseat. Circulate out bottoms up while performing koomey recovery test. Test valves on choke manifold, OK, test flow sensor and found broken wire. Repair so audible alarm working. Break out tubing hanger and re-install flow nipple. Continue circulating while working on PVT equipment. Hole taking 4 bph. Page 3 of6 15-Aug-2003 16-Aug-2003 17-Allg-2003 18-Aug-2003 19-Aug-2003 A urora Gas, LLC TOH wi 3 Y2" tubing. Pull 3 Y2" pipe rams and install 2 3/8" rams. Function and pressure test same. Problem discovered with BOPE remote control panel when blind rams closed and crushed 2 3/8" tubing pup joint. Install test plug and inspect blind rams. Pressure test, OK. RIH with 3 Y2" tubing scraper on 2" blast joint and 2 3/8" tubing to 2370'. Circulate and work tubing to clean up. Encounter "asphaltic paraffin" material at 2370 and cannot work deeper. POOH. LD scraper and pick up Baker C 1 packer on tubing and RIH for squeeze cementing. TIH to 1800' and wait on weather to fly in BJ Services cementers. Cementers on location, rig up, set packer at 2340', fluid pack back side and initiate cement squeeze over lower perforations through gravel pack. Pump 75 bbls cement and displace away with 8.25 bbls brine. Release packer, reverse circulate and POOH to 2320' WOC. RIH and set packer at 2320', fluid pack back side, establish injection rate and squeeze .75 bbls cement. Release packer, reverse circulate and POOH to 1775'. WOC. RII-I to tag last cement plug, no cement. Set packer at 2330', fluid pack backside of packer, establish injection rate at .5 bpm and squeeze 5 bbl 15.5 ppg cement. Hesitate squeeze by displacing with 3 bbls fluid. Wait 10 min; pump 2.5 bbls for 550 psig backpressure. Hold pressure until bleed off to 300 psig, and pump .25 bbls displacement for 500 psig pressure. Bleed off and release packer, reverse out, POOH clear cement. WOC. RIH and tag hard cement at 2319'. POOH and strap out. Rig up and RIH with B1's roto-pulse tool. Wait until daylight to pump methanol. COlnplete Rig up ofBJ Roto-Pulse tool and Nitrogen equipment. RIH and treat perforations from 2005' - 2032', 2201' - 2238' and 2302' - 2308' with 101 bbls 3% KCl solution containing 25% methanol and surfactant. Flush lines with water and POOH to lay down Roto-Pulse tool. PU and RIH with completion string and packer stab-in seal assembly with 1.9" tubing tail blast joint. Land seal and determine space out. Pick up, space out, install tubing hanger and land hanger in tubing spool. Lock down. RU slickline tools on sand line. RIH to shift sliding sleeve to place packer fluid. Could not get "X" profile shifting tool to latch. Call out Pollard and mobilize slickline equipment from Beluga. After numerous attempts, latch and open sliding sleeve. Displace packer fluid. RIH and close sliding sleeve. Pressure test back side to 500 psig, OK. Cannot get X-profile plug to seat in landing nipple after numerous attempts. RIH with collar plug on slick line and set. Test tubing to 2500 psig, Pull collar plug and RD slickline. Set backpressure valve in tubing head and rig down BOPE. Rig up wellhead and pressure test wellhead to 2500 psig, OK. RU BJ Services to pump nitrogen. Pump 23000 scfN2 at 1625 psig. When done, SITP at 1100 psig. Flow back well through Page 4 0/6 choke, gas to 1400 units then well dead. Rig down and prepare to swab in well during daylight operations. 20-Aug-2003 Swab to 1740 ft and pulled 36 bbls water. Gas to 3600 units. Shut in well and pressure build up to 15 psig. Continue swabbing at 30 minute intervals with total fluid swabbed of 90 bbls. Treat well with 10 gallons detergent and suspend swabbing due to dark. Shut in well until following AM. 2l-AlIg-2003 Swab well, found fluid level at 600 ft. Swab at 30 min. intervals. Total fluid pulled, 121 bbls. Rig down and release rig. Decision made to bring in Pollard for remainder of swabbing. 27-AlIg-2003 Pollard on site at 1530 hrs, MI, RU and begin swabbing using slickline truck. Initial fluid level at 760 ft. Swab total of 5 bbls. Final fluid level 5 bbls when well shut in for night. 28-Aug-2003 Swabbing using slickline. Initial fluid level at 760 ft. Final fluid level at 800 ft at end of day's activities. Total volume swabbed 24 bbls. 29-Aug-2003 Swabbing using slickline. Initial fluid level at 760 ft. Final fluid level at 900 ft at end of day's activities. Total volume swabbed 20 bbls. Shut down to install braided line on drum for remaining swabbing. 30-AlIg-2003 Finish installation of braided line and pack-off on lubricator. Start swabbing with initial fluid level at 760' and 100 psig at wellhead. Blew out a-ring on lubricator pack-off pump. Shut down while rebuilding pump. Resume swabbing with occasional gas. Final fluid level at 1300 ft. Secure well for night. Total volume swabbed 41 bbls. Well occasionally kicks and tries to unload then dies. Have now swabbed total of 206 bbls since swabbing activities started at completion of well. 31-AlIg-2003 Swabbing well with intennittent gas flow. 01-Sept-2003 Arrive on site, SITP = 100 psig. RIH with swab and find fluid at 1400'. Swab 14 runs, with well flow for 5 - 20 minute intervals between swabs before die off. Total fluid swabbed 59 bbls, for total of 319 bbls since end of workover. 02-Sept-2003 SITP 110 psig on arrival. RIH with swab and fluid at 1100'. Well flowed 20 min. after 1 st run. Caught water sample after run 5 and found CI = 19,000 ppm, 1.024 specific gravity indicative of 4% KCI workover kill fluid. Fluid at 1250' on run 8. Total fluid recovered over day 37 bbls for total of 348 bbls of 709 used. Aurora Gas, LLC Page 5 of 6 03-Sept-2003 SITP 60 psig on arrival. Rill with swab and fluid at 1100'. Swabbed well 5 times with intermittent flow between runs. Total fluid recovered over day 32 bbls for total of380 bbls of709 used. 04-Sept-2003 SITP 210 psig on arrival. Open well to flow. Flowed water with intermittent gas 22 minutes until flow ceased. SI and built to 280 psig in 10 minutes. Open well and flow until pressure dropped and flow ceased. Repeat procedure all day. Made 1 swab run but no fluid. Well will flow at 100 psig for short duration. Decision made to RD lubricator and release Pollard slickline. Total fluid recovered for day = 26 bbls. Recovery to date = 406 bbls of 706 bbls used. Mid day water sample showed CI = 20,000 ppm, Ca = 800 ppm and wt = 8.42 ppg. SI for nite. 05-Sept-2003 thru 17-Sept-2003 Well blown down intermittently when personnel available in attempt to achieve sustained flow. Observed SITP of 550 psig on occasion but well will still not flow commercially. Well flows until pressure drops to level that will not unload water. To date total water recovered 621 bbls of 709 used for kill and workover procedure. Water analysis on sample taken on 17-Sept-2003 indicated CI = 17,000 ppm, K = 8300 ppm and specific gravity = 1.02 indicating 8.5 ppg workover brine still being returned. Well will be blown down and checked for deliverability when resources permit. Shut in well until further attempts can be made to blow down for clean up and production. 16-Nov-2003: Pollard wireline unit to location. Rig up lubricator. SITP-500 psi. 17-Nov-2003: Hold Safety meeting and discuss job plans. RIH wI 1,87" tubing punch on wireline and set down on sliding sleeve at 1751'. POH, file down tool, and rerun. Set down on blast joint at 1851' KB. Punch Y4" hole. Pressure increased from 420 to 620 psi. POH. Add l' spacer bar below punch. RlH, Punch second Y4" hole at 1850' KB, POR. Rig down. Release wireline unit to Mobil Moquawkie #1. Aurora nos, fIr Paçp () of () Nicolai Creek No.3 Nicolai Creek Field D 0 Proposed Present Condition 2 3/8" 4.6# L-80 8rd EUE Mod Production Tubing to 1803' 2 eu. 1/4" holes in 2 3/8" tbg 1850' -1851 Sliding sleeve @ 1749' BOT Model "CMU" , wI built in 1.81 "x" landing profile. SS Requires "B" Shifting tool. 20" 85# Conductor @282' Cemented WI 720 Sks Locator Sub (4) Seal Subs (See BOT diagrams for all spec's) 02 inhibited KCI brine Packer Fluid in 2 3/8" x 13 3/8" annulus Baker Model DB Packer @ 1803' MD 7" Sliding Sleeve @ 1812' Baker Model DB Packer 65/8" 32# Bottom Guide 6 5/8" 32# Mill out Extension 7" Sliding Sleeve 6 5/8" 32# Lower Extension (See BOT diagrams for all spec's) 10.63" OD 47# Bakerweld Screen (9 5/8" Pipe wI 8.681" ID) @ 1900 -1931' 2 3/8" 4.6#/ft 8rd EVE Tbg @ 1793' - 1853' hung off seal assembly wI XO and 1,9" 2,76#/ft 10 RD APIIJ Blast Joint tail pipe from 1853' - 2289' inside Screen for velocity string. Perforatio ns 1900' - 1930' MD Perforations 2005' - 2032' MD Well Gravel Packed with 29,744 Ibs of 12/20 sand from 1812' - 2478' in 2000. Perforations 2201' - 2238' MD 4 1/4" OD 9,2# Bakerweld Screen (3 1/2" Pipe wI 2.992" ID) 1933' - 2346' Perforatio ns 2302' - 2328' MD New PBTD @ 2319', Squeezed gravel pack, lower screen and lower perforations with 6.5 bbls cement to shut off water from lower perfs. TOe tagged at 2319' Perforations 2360' - 2380' MD :ft,+ í"ì, :M If\,!\. '/ i); it ,r !~ t¡"',I~t,, ,.,', ','~, ( ~1!4,',~,\ ~,~,': ','. ;'I;rl .' 1\,',;') \¡'~ ~:,fìt Original PBTD@ 2478' :\~,.Y f~~7f""",~,:;,..,', :if~ ~,~<t, , :~J ,r r..)~.' ,d , .' :':,: ':"~: .\', . 'i !.,..', v' H,;' '" , " , ..'" ..1J .~., . . '. ':"'il'.~:,l......~~;; ""~' f,l' ~ ..'.,II:,~ ,... ',II' " . "', '. ',~". :>, . 'I . ".J "~",.-, .'1 ,,, ,>', '", If "";',; : If. ',;:.,:~~;;-."':t,\\,,: 'I'" .;õ"',', ":".1):' ',~ " ", ~.>:~,~u't!'~, .' . ',\ ~"~ ~~~~r,') :'- .,\ 'i ,i..'", ,,:"~:?:J;.I ': I . '" ,,',,- :1'."" J' , '. 'I' . ,," .... ' . , :. .' ,I':"',,; 4~" 'Ii.. " ,:":"-',','~',;" ... Bullplug @ 2385' Figure I 7" 29# N-80 Liner @ 2522' Cemented WI 220 Sks Cmt PTD: 167-007 API: 50-283-20003 Workover Start Date: Aug. 1, 2003 Work Completion Date: Aug. 25, 2003 Elev. (RKB) 16' (Ground Elevation 246' AMSL) All depths are RKB measured depths. Nioolai Creek #3 Fairweather E&P Services, Inc. Rev. 04 DHV 04-December-2003 Drawing Not to Scale Aurora Gas, LLC NCU #3 Completion Tally (8/2003) All components below seal assembly are hung off inside original gravel pack completion installed 12/2000 Component Length Depth Tubing Hanger 3 1/2" Pup (9.2# EUE 8rd L-80) 2.12 2.12 3 1/2" B x 23/8" P Xover 0.99 3.11 57 Jnts of 23/8" (4.6# EUE 8rd Mod L-80) 1745.46 1748.57 Sliding Sleeve (BOT CMU wI "X" profile & liB" shift profile 8.06 1756.63 1 Joint 2 3/8" (4.6# EUE 8rd Mod L-80) 28.9 1785.53 Seal Assembly wI XO's 7.14 1792.67 2 Jnts 2 3/8" (4.6# EUE 8rd Mod L-80) 59.98 1852.65 23/8 to 1.9 Xover 0.7 1853.35 22 Jnts Blast 1.9" 2.76# 10rd API 435.48 2288.83 RKB= 16' GL: 246' Packer Depth 1803' NOTE: See original completion diagram for detailed information on all gravel pack completion hardware installed. Figure II , ,,) ". .... ..---, I ! EQUI'tÆNT AND SERVICES lOCATIC1'4 --,- OI'ERATCF< --"-, CCMPANY REP, 1 ---- F lEU) STAiE'"'--- 2 Alaska -'--' LOADING DOO< Baker Oil Tools Sand Control Aurora Gas, LLS Nicolai Creek 3___, RIG NAME 4 Inlet Drilling PREPARED ~ D.P.Byrd DATE SUBMrTTED ' 20-Dec-00 JOB REP~- 5 No, 6 7 8 9 10 11 12 13 14 15 26 27 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 DEPTH 1803.14 1806.44 1807,34 1812.13 1815.07 1830.77 1831.52 1833.45 1835.3 1865.3 1895.39 1898.29 1900.26 1931.08 1933.2 1970.81 2008,36 2045.94 2083.46 2121.06 2158.59 2196.19 2233.84 2271.49 2309.14 2346.66 2384.31 2385 LENGTH 1803.14 3.3 0.9 4.79 2.94 15.7 0.75 1.93 1.85 30 30.09 2.9 1.97 30.82 2.12 37.61 37.55 37.58 37.52 37.6 37.53 37.6 37.65 37.65 37.65 37.52 37.65 0.69 F"'- . PHONE. WELL 00, NO.3 LfASE PHONE. PHONE' PHONE. JOB. tv"",ioo I) WELL TYPE Gas 00 12.050 8.120 6.670 7.000 6.670 7.400 5.650 5.500 5.500 5.500 5,500 9.625 10.630 9.700 4.250 4.250 4.250 4.250 4.250 4.250 4,250 4,250 4.250 4.250 4.250 4.250 4.250 SALES lOCAT1ON r&ií8 BAKER HUGHES Baker Oil Tools Kenai,Ak. 907-776 8131 B>P BHT Baker Oil Tools MAX OEV, ZWE œv. Page: 1 sææN SIZE ST ARUIG WELL SAND SIZE ' COMPlETION R.UID (-'gtT1 or<! Iype) COATNG 11ype) PERFORATIONS SIZE WEIGHT GRADE THREAD - CASING LINER TUBING WRKSTR. 10 DESCRIPTION Top Of Packer 4.750 Baker 240-47 Model DB Packer #424-02-91 OOQA 4.875 194-32 Bottom Guide 6 5/8-32# 5.675 6 5/8-32# Mill-out Ext. 4.750 190-47 Sliding Sleeve #487-06-4785 5.675 Lower Ext. 65/8-32# -#066267211 4.500 X.D.6 5/8-32# Butt. Box X 5 SLHT Pin 3.500 Baker KDIV #487355047 4.408 X.D. 5-15# SLHT Box X 51/2-15.5##SLHT Pin 4.950 Blank Pipe 5 1/2-15.5# 4.950 Blank Pipe 51/2-15.5# 4,950 Pup Joint 5 1/2-15.5# 5.950 X.D. 5 1/2-15.5# SLHT Pin X 9 5/8-47# Butt. Pin 8.681 95/8-47# Bakerweld Screen 2.992 X.D. 95/8-47# Butt. Box X 31/29.2# SLHT Pin 2.992 31/29.2# SLHT Bakerweld Screen 2.992 31/29.2# SLHT Bakerweld Screen 2.992 3 1/2 9.2# SLHT Bakerweld Screen 2.992 31/29.2# SLHT Bakerweld Screen 2.992 3 1/2 9.2# SLHT Bakerweld Screen 2.992 3 1/29.2# SLHT Bakerweld Screen 2.992 3 1/2 9.2# SLHT Bakerweld Screen 2,992 31/29.2# SLHT Bakerweld Screen 2.992 3 1/29.2# SLHT Bakerweld Screen 2.992 3 1/29.2# SLHT Bakerweld Screen 2.992 31/29.2# SLHT Bakerweld Screen 2,992 3 1/2 9.2# SLHT Bakerweld Screen 3 1/2 9.2# SLHT Bullplug T.O. Figure II Continued... Original Packer and Gravel Pack Completion Intact in Well 12/2003 "', AURORA GAS FIELD 907 583 2239 p.2 19-August-2003 R-t~ 1;!27/~3 ~ \cC) \~\ C,'c \i- ~ State of Alaska AOGCC Mr. Tom Maunder Anchorage, AI( ( ~ "ì -aCJ'l Subject Nicolai Creek Unit #3 - BOP Test Variance. Dear Mr. Tom Maunder; J~ f\<è? Mr. Jack Keener, Company Man for Aurora Gas spoke to Jeffeew&S concerning a possible variance on the BOP test. The necessary equipment was located to retest the 2 3/8" pipe rams as we1l the blind rams prior to commencing further operations. Based on the fact the rams were retested a request for variance was not pursued. The pipe and blind rams were tested to 500 psi and 3000 psi on August 15 between 11:30 am and 11:50 am. If you have any further questions or concerns please contact me on the rig at 907-440- 5500. fldin rely; ,~ D\~ aul D. Roberts Aurora Gas - Company Man cc: Duane Vaugen ~CA[~!h.t~rc.:lf.)' li~ F ['1) G]¡ fÎÌI 200']). D't!~E" 11) Ie. ~ Q» 0 .J "". AURORA GAS FIELD 907 583 2239 p.l I '. ----.....---."..----.. .,-...,--,....-...-......-J--...-.....----,.---...........-.---,--.-,.----..--, _.n. ,.....--..--,..--.1- ""-".--'.-----...... ,_... '--, ;;:;:/?¡~g .'..'c,,"" ',,',:.',: ',"','.';>".:.t: \", t' '; ë.. ::;':~ il: Y ;: ::; ~:: :¡'. ;,~ ;,' ~:}~i:!¡j;~;:;, '0 L'::.;:¡,:..';":" N.. ""-',"" : ," "'" ,,'or'" 1,00,','0",',', .. ,":;::'::: :,<1 !" "0 t.: ." ,~ i-; '" ~ ~ ;:; ¡"i~~:, f'" ' "'.\ ------. '-----' ! r, ¡:¡~ - 03 I - v, - -- ;1/( ~ '(! r 10 /O/'YI i I 7'ldh1 'I p~! 41 ~/-I-5 I I I 01 fay~s " '. . I i .J. ~) 'ig' ~~:~,;,:;.::' "'. :..,~r,.,;:..\ ~..:, . i" P ,'"'iI'\'-. ';;;1 ~I."'.' ...I'.í '",',\".~." ""':'í' """"'. " ',,',' ¡..,~ "~;.:--;:~~~"'f 'v ' """""" i.""",~,' A'lil """( ! .. "" ,;:,11;';",,: ~k1~t~i/.,\' " i'f " .' '(A,.'¡',i!I"¡'", . '. ¡',¡B~On November 5, 2003 G. Scott Ffoff, President Aurora Gas LLC 1029 West 3rd Ave., Suite 220 Anchorage, AK 99501 Dear Sir: Will the recent workover of r~icholai Creek No. 3.~'lell increase production from ADL-632797 Thank you for your early reply. Sincerely, John R. Roderick cc. AK 0il & Gas Conservation Commission 333 ~est 7th Ave., Suite 100 Anchorage, Ak 99501 1620 H~DDEN LANE ANCHORAGE, ALASKA 99501 907-272.8089 PHONE/FAX E-MAIL: r~!cs._~ ~IPEG image 1024x768 pixels Subject: Aurora Nicolai Creek #3 BOP test Date: Mon, 11 Aug 2003 11:42:42 -0800 From: "JeffB. Jones" <jeff__jones~admin.state.ak.us> Organization: AOGCC To: James B Regg <jim regg~admin.state.ak.us> CC: Tom Maunder <tom-_maunder~admin.state.ak.us> Hello Jim, I witnessed a partial BOPE test at Aurora's work over operation on the Nicolai Creek #3 well yesterday. The testing had not finished by the time the rig crew went off shift at 7 pm (1 crew daylight shift only) and since they had several repair items I suspended the testing and plan to return and finish up when repairs are made. Their procedure is to shut in the well with the blind rams during the night when the rig crew is off shift. There were some discepancies I would like to make you aware of: 1. 2 choke manifold valves failed pressure tests and Kill HCR not closing properly 2. The gas buster was not operational & no fluid return line to mud system (Vac truck?) 3. The Koomey unit failed the recharge test (200 psi build: 1:25; full recharge:5:57) 4. No remote BOPE closing unit on rig floor 5. No PVT system on rig floor 6. Insufficient nitrogen capacity for back-up BOPE operation ( 1 bottle @ 1500 psi) 7. No mud cross: Choke & kill lines flanged to the casing hanger spool Outlets. I spoke with Jack Keener (Aurora Representative) this mornining and he indicated repair of these items is progressing, however they are "'weathered in" today. He has made arragements to aquire a Koomey package from Swaco with a bigger pump, more accumulator and nitrogen bottles and a remote BOPE panel for the rig floor that will be installed in place of the current system. A PVT monitor will be installed on the rig floor and the failed components will be repaired and ready for re-test in a few days. Please note that this is not a typical Alaska rig configuration, rather it is a mobile workover rig with trailer & skid mounted packages and an open air design that was slightly modified for drilling & workover use in Alaska. I will keep you informed as the situation progresses. Thanks, Jeff 1 of 4 8/11/3.::'(73 12:11 PM JPEG image 1024x768 pixels 2 of 4 8/11/2003 12:11 PM JPEG image 1024x768 pixels !~0. ,.. ,,~ '" ~ .. ;.'i ..,.t i~-' "-, . ".. ~. '.'.;.':~. 'd:;~' :17" · .." i=,...z.'..:." · '~., ,:,...'?. ~.; ..... ::*~ .4::;!-:~,;."!' '. ' · ., "t'~..~?~'.... ,;%r!/'*" . "" i;". "~:"L%' ' . · '~,.~,'~,~i~vi">?' [~g,' ¢ " ... 5:!.,:-' ...,.O.-~:[: :o-'!' ' ' ' :"' ~'¢"' "."<'.'>}.t:* ' ' -t.?23:-.{:x--'..- ---- .... ,..... .' ..'i;.:!.,~,...~',?' '. .. '... ,'ii'! ' ...'¢'~!'i:'~:>'"'". · -'. :.' ;"¢'2. , · ?~': .' ' ': 72. ,;" :j ~,,,:. : . ,.. i'~ "¥. ". ".' ..;'~ '.' · v::"..,:... ", .'.. '"'i"'7 .., .'.)i.,!?'"" .,v::.~.~ ". '""":'i" .':" ' '".": :' ' ' ' · .5.:'..:' :. ....,., ,,, .....)~:s.',.~- .... 3 of 4 8/11/2003 12:11 PM JPEG image 1024x768 pixels 4 of 4 8/11/2003 12:11 PM ALASKA OIL AND GAS CONSERYA ION CO SSION / / 1' FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 30, 2003 Mr. J. Edward Jones Vice President Operations and Engineering Aurora Gas, LLC 1029 W. 3rd Avenue, Suite 220 Anchorage, AK 99501 Re: Request for Variance of BOP Requirements at 20 AAC 25.285(c)(9) Nicolai Creek Unit #3 (167-007) (303-175) Dear Mr. Jones: Your request for Variance of BOP Requirements of 20 AAC 25.285(c)(9) for the proposed workover operations on Nicolai Creek #3 is approved. (Please note that !dour request citing 20 AAC 25.035 (4)(F) was incOrrect. The Commission assumes that you meant to cite 20 AAC 285(c)(9) which relates to workover operations with the tree removed.) Specifically, you requested to employ the tubing spool on the well in lieu of installing a choke/kill spool because there is insufficient space available below the rig floor to install the required combined rams, annular and the choke/kill spool. This proposal will provide an equally effective means of well control. A copy of this variance letter should be kept at the rig site. Please contact Tom Maunder at 793-1250 for further assistance. Sincerely, Sarah Palin Chair cc: Duane Vaagen, Fairweather E&P NOTE TO FILE Aurora Gas, LLC Variance Request for Choke/Kill Spool Nicolai Creek #3 (167-007) (303-175) Aurora Gas, LLC has made an application for a variance to the requirements at 20 AAC 25.036[e](4)(F). Aurora requests to attach their choke and kill lines directly to the tubing spool rather than employ a choke/kill spool. This document analyzes Aurora's request and recommends approving it. Aurora has an approved sundry (303-175) to perform a workover on the subject well. According to the regulations, well control equipment must be employed while conducting the proposed work. Aurora's request is for a variance to the choke/kill spool requirements at 20 AAC 25.036[e](4)(F) contained in the drilling portion of the regulations, however the correct citation should be 25.285(c)(9) contained in the workover section of the regulations. The sections are essentially equivalent. The reason for Aurora's request is that there is insufficient height available below the rig floor to accommodate the choke/kill spool specified in the regulations. Raising the rig to provide the needed clearance to install the choke/kill spool is not an easily accomplished task nor is it without cost. As an alternative, Aurora proposes to install the choke and kill lines directly to the tubing spool already in place on the well. The purpose of the choke/kill spool is to eliminate the potential for circulation activities to cause wear in a wellhead component that is not usually replaced. 20 AAC 25.285(h) allows the Commission to approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. Aurora's proposal substitutes the tubing spool for the choke/kill spool. The tubing spool meets the remaining requirements of 25.285(c)(9). The need to circulate via the tubing spool outlets should not be great during the workover. The initial circulation to kill the well would be conducted via the tubing spool, but this activity would be the same if a choke/kill spool were employed. During the actual workover, there should be no need to use the spool outlets unless a well control situation were to be encountered. Nicolai Creek #3 presently makes water with some gas and although the intention of the workover is to eliminate the water, the produced gas is essentially pure methane at relatively Iow pressure. If significant circulation were to be done using the tubing spool outlets, Aurora would have the ability to set a retrievable plug in the casing and inspect the tubing spool for damage. Ultra-sonic inspection methods might also be employed to assess the condition of the tubing spool. I recommend approval of Aurora's request to substitute the tubing spool for the choke/kill spool specified in the regulations. Tom Maunder, PE Sr. Petroleum Engineer July 29, 2003 28-July-2003 Aurora Gas, L L C www. aurorapower, com Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for approval to use alternate BOP equipment per 20 AAC 25.037 while performing work-over on well Nieolai Creek No. 3. Dear Ms. Palin: This letter and attached exhibits are being submitted to request approval for use of a BOPE configuration that is not currently listed in the 20 AAC 25.035 (4)(F) rules that apply to well work-over and completion operations. The BOP configuration requested herein, differs from that originally proposed and approved in the Sundry application submitted and approved to perform the well work on Nicolai Creek Unit No. 3. Aurora Gas, LLC requests permission to use and configure the tubing spool currently in place in lieu of installing a separate drilling spool. The tubing spool fills all of the requirements and ratings of a built for purpose drilling spool with the exception of naming and extra machining to accept a tubing hanger. Please see attached Exhibits I & II for reference. Permission is requested to use the configuration indicated for the following reasons: · Due to rig configuration, there is insufficient clearance below the rig floor to install a drilling spool in addition to the tubing spool already in place. To modify the rig to accommodate an additional drilling spool, a substantial expenditure would be required. The rig that will be used, Aurora Well Service No. 1, has a maximum drill floor elevation of 14' AGL. The top of the BOP stack as proposed using the tubing spool as installed brings the top of the flow nipple to floor level. Installation of a separate drilling spool in addition to the tubing spool would add an additional 27" to the top of the BOP stack which is unacceptable from both a safety and rig operations point of view. (see Exhibit). · The tubing spool which is currently configured with (2) two, 2 1/16" 5(M) valved outlets (see Exhibit II, production tree) would require only the installation of remote choke and kill valves and lines to allow full function as a drilling spool. · The BOPE configuration requested is already an acknowledged and approved method of secondary well control as indicated in 20 AAC 25.036(4)(F), which deals with secondary well control for through-tubing drilling and completion. 10333 Richmond Avenue, Suite 710 · Houston, Texas 77042 · (713) 977-5799 · Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220 · Anchorage, Alaska 99501 ° (907) 277-1003 · Fax (907) 277-1006 Ms. Sarah Palin Page 2 A Sundry notice has already been submitted and approved for the work-over of Nicolai Creek No. 3. Equipment mobilization will begin on August 1 st 2003 and well operations will begin shortly them-after. If you have any questions, please contact the undersigned at (907) 277-1003, or Duane Vaagen at (907) 258-3446. Sincerely; j~E. dwar~ d_~Jones ~ Vice President Operations and Engineering Aurora Gas LLC. Attachmems: cc: Duane Vaagen Nicolai Creek Unit No. 3 13 5/8"5M BOPE Stack configuration Special Design, load bearing riser / flow nipple Flow Line to Pits Rig Floor 14' AGL Fill up Line 5' /\ 60" 5M Annular Preventer 135/8"5MDoubleGate I~I I I Pipe Rams sized to work string. Blind Rams 3.75' I 4.23' 45" 50.8" " Valve_ 5M Hydraulic (ill Line) -'"'~~~~L!'' "'~~~:~[~ 1' ~ 12" //Ground Level// 1/4" X 13 5/8" 5M Tubing Spool ~' I '1 ~ 5M Hydraulic Valve (2) 2 1/16" 5M Manual Valves 21 1/4" 2M E~ ~]~1][~ (Choke Line) Casing Head 2" 3M Manual Valve On Wellhead -- Conductor -- 20" Casing - 13 3/8" Casing Exhibit I Nicolai Creek Unit No. 3 13 5/8"5M Production Tree Currently Installed 3-1/8" S,000 Tree Run 13-5/8" 5,000 // 3-1/8" 5,000 Wing 2-1/16" 5,000 1~2" AGL lTl/l/ 21-1/4 2,0( 20"CSG 13-3/8" CSG ~ 3-i/2" TBG -"" 2-1/16" LP Cellar 21 w/ Exhibit II ~ra Well Service #1 BOP System ] Fairweather E&P Services, Inc. Rev. 02 DHV 28-July-2003 Drawing Not to Scale I I Auror~ Aurora Well Service Rig No. 1 Proposed Choke / Kill Manifold Configuration All valves are 3" rated at 5000 psi. Output to Pits Inlet from BOP Choke Line Hydraulic Remote Activated choke 3" 5M Rated Valves 2" 5M Rated Valves 3" 5M Rated Valves 3" 5M Rated Valves Bleed Flare Line to Open Flare Pit Manual Choke 2" 5M Rated Valves To Gas Buster "Atmospheric Degasser" Jrora Well Service #1 Choke Manifold I Fairweather E&P Services, Inc. I Rev. 01 DHV 20-Jun-2003 [ Drawing Not to Scale [ I AL Aurora Gas, L L C www. aurorapower, com 28-July-2003 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for approval to use alternate BOP equipment per 20 AAC 25.037 while performing work-over on well Nicolai Creek No. 3. Dear Ms. Palin: This letter and attached exhibits are being submitted to request approval for use of a BOPE configuration that is not currently listed in the 20 AAC 25.035 (4)(F) rules that apply to well work-over and completion operations. The BOP configuration requested herein, differs from that originally proposed and approved in the Sundry application submitted and approved to perform the well work on Nicolai Creek Unit No. 3. Aurora Gas, LLC requests permission to use and configure the tubing spool currently in place in lieu of installing a separate drilling spool. The tubing spool fills all of the requirements and ratings of a built for purpose drilling spool with the exception of naming and extra machining to accept a tubing hanger. Please see attached Exhibits I & II for reference. Permission is requested to use the configuration indicated for the following reasons: Due to rig configuration, there is insufficient clearance below the rig floor to install a drilling spool in addition~to the tubing spool already in place. To modify the rig to accommodate an additional drilling spool, a substantial expenditure would be required. The rig that will be used, Aurora Well Service No. 1, has a maximum drill floor elevation of 14' AGL. The top of the BOP stack as proposed using the tubing spool as installed brings the top of the flow nipple to floor level. Installation of a separate drilling spool in addition to the tubing spool would add an additional 27" to the top of the BOP stack which is unacceptable from both a safety and rig operations point of view. (see Exhibit). · The tubing spool which is currently configured with (2) two, 2 1/16" 5(M) valved outlets (see Exhibit II, production tree) would require only the installation of remote choke and kill valves and lines to allow full function as a drjl~ · The BOPE configuration requested is already an acknowledged and approved method of secondary well control as indicated in 20 AAC 25.036(4)(F), which deals with secondary well control for through-tubing drilling and completion. 10333 Richmond Avenue, Suite 710 · Houston, Texas 77042 · (713) 977-5799 ° Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220 · Anchorage, Alaska 99501 ° (907) 277-1003 ° Fax (907) 277-1006 Ms. Sarah Palin Page 2 A Sundry notice has already been submitted and approved for the work-over of Nicolai Creek No. 3. Equipment mobilization will begin on August 1 st 2003 and well operations will begin shortly there-after. If you have any questions, please contact the undersigned at (907) 277-1003, or Duane Vaagen at (907) 258-3446. Sincerely; j~l~. dward~~Jones ~ Vice President Operations and Engineering Aurora Gas LLC. Attachments: cc: Duane Vaagen Nicolai Creek Unit No. 3 13 5/8"5M BOPE Stack configuration Special Design, load bearing riser / flow nipple Flow Line to Pits 5M Annular Preventer 13 5/8" 5M Double Gate [~ Pipe Rams sized to work string. Rig Floor 14' AGL Fill up Line 3.75' 60'! 45" 4.23' 50.8" Blind Rams ~" 5M Hydraulic Valve..~ Kill Line) ~"-~.~~ 1/4" X 13 5/8" 5M Tubing Spo '(2) 2 1/16" 5M Manual Valves 21 1/4" 2M Casing Head 1' ~ 12" J/Ground Level J~ 3" 5M Hydraulic Valve [[[1~ (Choke Line) 2" 3M Manual Valve On Wellhead -- Conductor -- 20" Casing -- 13 3/8" Casing Exhibit I Nicolai Creek Unit No. 3 13 5/8"5M Production Tree Currently Installed //// 3-1/8" 5,000 Tree Run 13-5/8" 5,000 3-1/8" 5,0O0 Wing 2-1/16" 5,000 1~" AGL /~/ // / 21-1/4 2,01 20"CSG 13-3/8" CSG ~ 2-1/16" LP Cellar Exhibit II Auron Aurora Well Service Rig No. 1 Proposed Choke / Kill Manifold Configuration All valves are 3" rated at 5000 psi. Output to Pits Inlet from BOP Choke Line Hydraulic Remote Activated choke 3' 5M Rated Valves 2" 5M Rated Valves 3" 5M Rated Valves :i Flare Line to 3" 5M Rated Open Flare Pit Valves · '.~ Manual Choke ~ 2" 5M Rated Valves To Gas Buster "Atmospheric Degasser" ,urora Well Service #1 Choke Manifoldi Fairweather E&P Services, Inc. I Rev. 01 DHV 20-Jun-2003 I Drawing Not to Scale Aurora www. aurorapower, com 1 -July-2003 Commissioners Alaska Oil & Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED JUL 0 g ?_OO,3 Alaska Oi! & ,~,~s Oo!,.;. "' .......... ; .... "~ Anch0ra[ie Re: Application for Sundry Approval to perform well work-over procedures on the Nicolai Creek No. 3 gas well. Dear Commissioner(s): Aurora Gas, LLC is at this time seeking Sundry Approval of its plan to perform well workover procedures as required to resolve excessive water production problems and the associated decline in natural gas production related to said water. The Nicolai Creek No. 3 well was last worked on in December of 2000, when the well was re-perforated and a gravel pack was installed. The well has been on almost continuous production since the production facilities were installed in 2001. It is Aurora's intent to nm production logs to evaluate the production zones for water production and perform water shut-off treatments to minimize water production. The well will then be treated to reduce the suspected matrix/gravel pack water blockage, which may be interfering with gas production. The 3-½" production tubing will then be / replaced with 2-3/8" diameter production tubing string to increase flow stream velocities thereby aiding NCU #3's water unloading capabilities. The AOGCC will be notified at /¢' the conclusion of well work operation of the final configuration of NCU #3. Please see attached Exhibits I and II for current and proposed completion information. The anticipated operations start date is July.10, 2003. At this time, pore pressure is estimated to be 650 psi. A recent pressure / temperature survey cor)ducted while producing returned a maximum flowing bottom hole pressure of 517 psia./ This equates to a pressure gradient of.27 psi / fi at 2380', the deepest perforation. Based on this information, a 3% KCI solution will be of sufficient density '/'' for well kill operations. A 13 5/8" (5M) BOP system will be used. BOP tests will be performed Please see attached diagram of BOP system ' .~. ~rtacnments include the following: 1) Form 10-403 Application for Sundry Approval 3 - Copies ORIfilNAL 1029 W. Third Ave., Suite 220 · Anchorage, Alaska 99501 · (907) 277-1003 · Fax (907) 277-1006 10333 Richmond Ave., Suite 710 ° Houston, Texas 77042 · (713) 977-5799 ° Fax (713) 977-1347 Page 2 Commissioner(s) contd... 2) 3) 4) A summary of the intended well work procedure and operations plan Sketch of current and proposed final well completion scenario. A sketch of BOPE equipment that will be used If you have any questions or require additional information, please contact the undersigned at (907) 277-1003 or Duane Vaagen at (907) 258-3446. Sincerely, I / ' / ,~' ,.'J'. Edward Jones Vice Presidem. Operations and Engineering Aurora Gas, LLC CC.' Andy Clifford Duane Vaagen Att: n GINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 2. Name of Operator [ ]Abandon [ ] Suspend I ] Plugging [ ] Alter Casing [X] Repair Well [X] Pull Tubing [ ] Change Approved Program [ ] Operation Shutdown [ ] Re. Enter Suspended Well Aurora Gas, LLC. 15. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service 3. Address 1029 West Third Avenue Suite 220 .. Anchoraae. AK 99501 4. Location of well at surface 3369' FSL, 1668' FWL, Sec. 20, T11N, R12W, SM At top of productive interva (@ 1900') 3366' FSL, 1662' FWL, Sec 20, T11N, R12W, SM At effective depth (PBTD @ 2478') 3363' FSL, 1660' FWL, Sec 20, T11N, R12W, SM At total depth (~ 8841') 3035' FSL, 1290' FWL, Sec 20, T11N, R12W, SM 12. Present well condition summar~ Total depth: 8841' MD feet Plugs (measured) 8841' TVD feet Effective depth: 2478' MD feet Junk (measured) 2478' TVD feet Casing Length Structural Conductor 264' Surface 1985' Intermediate Production Liner 581' [ Time Extension [ ] Perforate [ Variance [X] Other ] Stimulate Workover as necessary 6. Datum Elevation (DF or KB) -216' KB 7. Unit or Property Name Nicolai Creek No. 3 8. Well Number No. 3 9. Permit Number 167-007 ' 10. APl Number 50-283-20003 / 1. Field and Pool Nicolai Creek 6890' - 7000', 50 sx cement 4915'- 5000', 50 sx cement 2478'- 2565', 100 sx cement Size Cemented MD TVD 20" 720 sx 282' 282' 13 3/8" 1770 sx 2001' 2001' 7" 220 sx 1941' - 1941' - 2522' 2522' Perforation depth: measured True vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) same JUL 8 200,3 3 1/2" 9.2# L-80 set at 1803' MD Baker 24047 Model DB Packer set at 1803' MD 13. Attachments [ X] Description of Summary Proposal [ ] Detailed Operations Program [X ] BOP Sketch 14. Estimated date for commencing operation .~'" 15. Status of well classification as: 16. If proposal was Venally approved ' [ ] Oil [ X] Gas [ ] Suspended Name of approver Date Approved Service Contact Engineer Name/Number: J. ~d~. ard Jones / (907)277-1003 Prepared By Name/Number: Duane vaagen/(907)258-3446 17. I hereby c"e~ ifY the the foregoing is,~rue' nd corr~ct to the best of my knowledge ..... Signed (~ 1 ...:.~act. e~ , ,,..., /'3 · '~.'~,~'"':'" ~/'~ ".;'~'.';2¢,//..,'/-¢ Title ~"/.~...~. /~'~,~"J~/~z'~'~,,,'",~-~,/-' Date ~///,/0 ~ .. // / ~///--""" - Commission Use Only Conditions/'bf~i~proval: Notify C/~isSi°n so representative may w~tness JApproval NO. '~5o~-' ?~- "~-/ Plu, in~( dg' g 'ty BOP Test ~ Location Clearance 'T'~.--%'[- ~ £) ~ ~ ~"°~~° ~~'~,Mechanical Integrity/Test Subsequent form required 10-. ~' ~ ~ '~~~~T~r~ ~ ~:~ J , order of the Commission ~~--,% ~ ~ Commissioner Date Form 10-403 Rev. 06/15/88 ~ Su ipli~;ate ORIGINAL AURORA GAS, LLC NICOLAi CREEK UNIT No. 3 PROPOSED WORKOVER PROCEDURE 1. Mob in and RU Slick-line equipment w/Memory Log w/Spinner, Temp, Pressure, Capacitance Fluid ID, and GR for correlation. RIH with tools and verify open tubing to bull plug at 2385'. With well open to production, pick up and record flow parameters across each perforated zone. POOH and process data for review. 2. Shut in well, isolate, bleed down and disconnect from flow line. 3. Move in work-over rig and rig up. Move in mud pumps and tanks: 1- rig pit, 1- open 100-bbl steel mud pit with gas buster, 1- tiger tank for workover water and rig pumps. 4. Kill well by pumping 3% KC1 brine solution down tubing. Check pressures on both 3 ½" tubing and 3 ½" x 13 3/8" annulus. Ensure well is dead and set back pressure valve in tubing hanger, ND tree. NU 13 5/8" 5M BOP stack. Test to 250/.150~psi. 'Pull back pressure valve. 5. Back out tubing hanger lock down bolts, RU and pull 3 ½" tubing w/hanger assembly. Break out hanger, LD, pull and LD tubing, strap and visually inspect (-1803' of tubing). Disconnect and lay out locator sub and seal sub assembly, breaking connections per BOT service rep. Have BOT service hand rebuild seal assembly on-site. 6. PU Baker Oil Tools Flow Test iPacker w/spacer joint and lower swab cup assembly. RIH and based on results of logging in step 1, prepare to treat suspect water producing zone(s) with water inhibition system "BJ Services, AquaCon". Set assembly // so packer is above suspect zone and swab cups are below. Using recommended BJ Services squeeze procedure, displace AquaCon into gravel pack and perforations. 7. POOH, Lay down packer assembly, PU Roto-Pulse tool. 8. PU, make up BJ Services RotoPulse tool to bottom joint, and RIH with 570' 2" FJ tubing, install 2" FJ X 2 3/8" 8rd EUE XO, PU and RIH with 2 3/8" 4.6 lb/ft tubing to 2384'. (Strap all tubing and crossovers prior to pick up and drift check all tubing while ie ing 9. Circulate 3500 gallons (83 bbls) of 3% KCI containing 25% by volume methanol and BJ Services surfactant (0.3% by volume) and solvent (0.5% by volume) additives to bottom of tubing and inject treating fluid using RotoPulse tool to penetrate gravel pack-- avoid area of AquaCon treatment. Displace over all and squeeze into all perforated intervals while POOH per BJ Services recommended procedure. POOH, stand back tubing and LD RotoPulse tool. 10. RIH with 570' ofT' 3.25 lb/ff FJ tubing and RIH. Install crossover to connect 2" FJ tubing to bottom of seal assembly. Pick up seal assembly w/locator sub, make up and connect to top ofT' tubing. Torque all seal assembly connections per BOT rep. 11. Pick up and install 3 V2" 8 rd x 2 3/8" 8rd EUE crossover. 12. Pick up and install one joint 2 3/8" 4.6 lb/f[ tubing. Install 1.875" id X-Nipple at one joint (-30 ti) above seal assembly. 13. Pick up and install one joint 2 3/8" 4.6 lb/ii tubing. Install 1.875" id sliding sleeve. 14. RIH w/2 3/8" tubing (-1780'). Land seal assembly, PU and install d~,,,~1/2'' x 13 5/8" tubing hanger w/1' x 3 1/5- pup joint below with 3 ~A" 8rd x 2 3/8'Dtr .(~,,,~,~ then space out with proper length 2 3/8"' pup joint(s). Land tubing hanger and lo'~'down. 15. RIH with slick line and install X-profile plug in landing nipple. Pressure test tubing to 2500 psi. Pressure test annulus to I000 psi. 16. RIH with slick line and open sliding sleeve. 17. Displace 2 3/8" x 13 3/8" annulus over to an inhibited 9.0 ppg brine packer fluid (-270 bbls). Displace with-6.9 bbls 3% KCI to place. ¸18. 19. RIH with slick line and close sliding sleeve. Pressure test tubing to 2500 psi. / Install BPV in tubing hanger at surface. Pressure test all to 1500 psi. 20. RD BOP, RU and install wellhead assembly. Pressure test to 2500 psi. Connect well to production facilities but do not open well to production. 21. Pull BPV, .RIH with slick line and pull plug in landing nipple. 22. Finish well treatment by over displacing well treatment fluids with nitrogen at 750 SCFM for 30 minutes. Open well to open tank through choke until methane content reaches LEL. Put well on production and monitor gas and water production. 23. RD and demob rig and ancillary equipment to next well site. 24. File 10-40~with AOGCC.//'' dhv / 30-Jun-03 Rev. 2.0 JEJ edited 6/30/03 Ixi Proposed Present Condition 3 112" Production Tubing Nicolai Creek No. 3 Nicolai Creek Field 20"85~ Conductor at 282' Cemented W/720 Sks Locator Sub (4) Seal Subs (See BOT diagrams for all spec's) Perforations 1900' - 1930' MD TOL @ 1941' Perforatio ns 2005' - 2032' MD Perforations 2201' - 2238' MD Perforations 2302'-2328' MD Perforations 2360'-2380' MD Baker Model DB Packer @ 1803' MD Sliding Sleeve @ 1812' 9 518"47# Bakerweld Screen @ 1900 - 1931' Baker Model DB Packer 6 518" 32# Bottom Guide 6 518" 32~ Mill out Extension 7" Sliding Sleeve 6 5/8" 32# Lower Extension (See BOT diagram for all spec's) Well has been Gravel Packed with 29,744 lbs of gravel. 13 318" 54.5# J-55 @ 2001' Cemented WI 1770 Sks Cmt 3 112" 9.2# Bakerweld Screen 1933' - 2346' Bullplug @ 2385' Exhibit I PBTD @ 2478'~::", · .~ Drilling Mul 7" 29~ N-80 Liner @ 2522' Cemented WI 220 Sks Cmt Drilling Mu~__ Drilling Mu 50 Sk Cement Plug from 491:5' to 5000' 50 Sk Cement Plug from -6890' to 7000' PTD: 167-007 APl: 50-283-20003 Re-Entry Start Date: Dec 6, 2000 Date Re-Completed: Dec 25, 2000 Elev. (RKB) 16' (Ground Elevation 246' AMSL) All depths are RKB measured depths. TD @ 8841' Nicolai Creek Unit #1 I Fairweather E&P Services, Inc. Rev. 03 DHV 23-June-2003 Drawing Not to Scale ~--~ Proposed Present Condition Nicolai Creek No. 3 Nicolai Creek Field 2 318" 4.6~ L-80 8rd EUE Mod Production Tubing to 1803' 20" 85# Conductor @282' Cemented W/720 Sks Locator Sub (4) Seal Subs (See BOT diagrams for all spec's) Perforations 1900' - Baker Model DB Packer.. / @ 1803' MD Sliding Sleeve @ 1812' Baker Model DB Packer 6 518" 32# Bottom Guide 6 518" 32# Mill out Extension 7" Sliding Sleeve 6 518" 32# Lower Extension (See BOT diagrams for all spec's) 10.63" OD 47# Bakerweld Screen (9 518" Pipe wi 8.681" ID) @ 1900 - 1931' TOL @ 1941' Perforations 2005'-2032' MD Perforations 2201'-2238' MD Perforations 2302'-2328' MD Perforations 2360'.2380' MD i PBTD @ 2478'?.~i Drilling Mu Drilling Mu, Drilling Mu 13 318" 54.5# J-55 @ 2001' Cemented WI 1770 Sks Cmt Well has been Gravel Packed with 29,744 lbs of gravel. 4 114" OD 9.2# Bakerweld Screen (3 112" Pipe wi 2.992" ID) 1933'- 2346' 2" 3 114 Iblft FJ Velocity String hung off seal assembly inside of Baker weld screen to 2380' Bullplug @ 2385' ',' 7" 29# N-80 Liner @ 2522' '~.L Cemented W! 220 Sks Cmt Exhibit II 50 Sk Cement Plug from 4915' to 5000' 50 Sk Cement Plug from -6890' to 7000' PTD: 167-007 APl: 50-283-20003 Proposed Re. Entry Start Date: July 1,2003 Work Completion Date: July 5, 2003 Elev. (RKB) 16' (Ground Elevation 246' AMSL) All depths are RKB measured dept,hs,. Nicolai Creek Unit #1 TO @ 8841' Fairweather E&P Services, Inc. Rev. 03 DHV 23~lune-2003 Drawing Not to Scale Nicolai Creek Unit No. 3 13 5/8"5M BOPE Stack configuration Flow Line to Pits Fill up Line 5M Annular Preventer ,/' Pipe Rams sized to work string. 13 5/8" 5M Double Gate 13 5/8" 5M Mud Cross 3" 5M Manual Valve (Kill Line) 3" 5M Hydraulic Valve. (Kill Line) ~ j3" 5M Manual Valve (Choke Line) j 3" 5M Hydraulic Valve ~ (Choke Line) 21 1/4" 2M X 13 5/8" 5M Casing Spool wi 2 1/16" 5M Manual Valves 21 1/4" 2M Casing Head 2" 3M Manual Valve On Wellhead Conductor -- 20" Casing Aurora Well Service Rig No. 1 Proposed Choke / Kill Manifold Configuration All valves are 3" rated at 5000 psi. Output to Pits Inlet from BOP Choke Line Hydraulic Remote Activated choke 3" 5M Rated Valves 2" 5M Rated Valves 3" 5M Rated Valves Manual Choke 3" 5M Rated Valves 2' 5M Rated Valves Bleed Flare Line to Open Flare Pit To Gas Buster "Atmospheric Degasser" urora Gas, LLC www. aurorapower, com April 26, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska 99501 RE: Nicolai Creek Unit No. 3 Form 10-421 Well Test Report Dear Commissioner Heusser: RECEIVED Attached is a Form 10-421 Gas Well Flow Potential Test Report for the recently completed test on thc Nicolai Creek Unit No. 3 well, following thc clean out, repcrforatc, and ~ravcl pack workovcr that was completed in December 2000 (Sundry Approval No. 300-247 and subsequent Sundry Report dated ]/26/0 !). The test was conducted between February 23, 2001, and February 27, 2001, and the well remains shut in pending installation of pipeline and production equipment, which is expected to occur in May 2001. These same producing horizons were previously tested upon initial completion in May 1967 and again in September 1979, and reports for those tests were filed with the Commission. Therefore, I don't believe that the filing of this report is required by the Regulations, but it is being done as a follow up to the Sundry Notice filed in January. Some notes about the test and the Report: 1) The pressures and temperatures were measured and recorded at surface (at the tree) with a quartz crystal electronic monitor--no down hole measurements were taken. A copy of the monitor output is attached. 2) The flow was measured downstream of chokes and separator using a 4" orifice meter with a two-pen recorder utilizing L-10 (square root) charts. Meter temperatures were read and recorded manually. Water rates were measured continuously with an electronic meter and recorded manually. A copy of the Field Test Notes is attached--note that the flow rates vary slightly from those reported on the Form due to the use of several constant F factors for field calculations, including Fpv= 1.0. 3) The bottom hole pressures and AOF were calculated using a Ryder Scott Company Excel spreadsheet macro. Therefore, some of the blanks in the Form 10-421 were not completed as the values were calculated within the spreadsheet and are not readily available. Other values such as Ps were taken from the macro. A copy of the Ryder Scott spreadsheet is attached. 5718 Westheimer, Suite 1180 · Houston, Texas 77057 ° (713) 977-5799 ° Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220 ° Anchorage, Alaska 99501 ° (907) 277-1003 · Fax (907) 277-1006 4) The well was flowing back gravel-pack load water during the test (recovering about 220 of about 1000 bbl. pumped), and this had an effect on both the bottom- hole pressures and the flow rates. The water production was considered in the calculation of the bottom pressures, but because water rates were decreasing and the well was cleaning up as the test progressed, the resulting multipoint test results were skewed somewhat. That the well was cleaning up throughout the test is obvious when looking at the overall test results, but it was not apparent when collecting data at each test point. At those times the pressure and rate had stabilized for at least 15 minutes, as preserib~ in the IOGCC Baclt-Pressure Testing of Wells Manual. Therefore, the resulting "n' value was greater than 1.0, which suggests the need to retest. However, as this fact was determined after the test was completed and because the results are adequate for Aurora's purposes, the AOF is calculated using n= 1.0, as prescribed in the Manual when n> 1.0. 5). Gas samples were taken during the flow test--copies of the analyses are attached. Please comact me at 713-977-5799 (or 277-1003 for the next several weeks) if you requffe any additional information. Sincerely, Aurora Gas, LLC Vice President Enclosm'es (6) cc: Bill Pe~ose, F~eather E & P Services STATE OF ALASKA ALA~ L AND GAS CONSERVATION ,MMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la- TEST: INITIAL ANNUAL SPECIAL b. TYPE TEST MULTIPOINT:k~ OTHER. STABILIZED [] NON STABILIZED [] CONSTANT TIME [] · ISOCHRONAL [] 2. Name of Operator 7. Permit to Drill No. Aurora Gas, LLC 167-007 3. Address 8. APl Number 5718 Westheimer,Ste. 1850, Houston, TX 77057 5o- 283-20003 4. Sudace Location of Well (Governmental Section & State Base Plane Coordinates) 1668'FWL, 3369'FSL,Sec.20,TIIN,R12W,SM 5. Elevation in feet (indicate KB, OF etc.) I 6. Lease Designation and Serial No. +216' (KB) I ADL-63279 12. Completion Date - 13. Total Depth {14. Plugback I.D. I 8841 ' 2390 ' Weight per foot, lb. I.D. in inches Set at ft. 5/14/67 16. Csg. Size ! 3-3/8'.!/7" 17. Tbg~ Size 3-1 /2" 18. Packer set at ft. lg03' 22. Producing thru: Tbg :J~ Osg, [] 25. Length of flow channel (L) 2140' ~,/1 5/'2CI 1'~ ¢;lr,/~ 1QA ')¢1/51 /10/11 V~/e'~g'ht )eTf%ot, Ib. ' .... ~.[J. ~n ........ inches s'et'a~'~ ' 9. 2.992 1808' 19. GOR cf/bbl. 20. APl Liquid Hydrocarbons · NA None 23. Reservoir Temp. 80 ''){- ° · Reservoir Press.8 7 6' psia @ Datum I 9 2 4 ~'VDSS VerticalDepth(H) l Gg 1%C32"1%N2 2140' P,5641 0.;!2 1.70 Flow Data Pressure psig 361 28. { Prove(Mtr RUDBek~ [Linc x Orifice No ] Size (in.) Size (in.) ~.' l~..026 2.0 2. ]~; 026 2.0 317 2.0 310 2.0 202 026 4~026 4';~026 2.0 9, Unit or Lease Name ~ r-r~l ~ ~ t~r~l~ fjD_it '~ b~- v~e-i i -R jrr~b e r ...... 3 169 hvv 5.1 1 9 .;"'2 2.9:7-' _ 89.8 137.8 34 34 34 36 33 11. Field and Pool Nicolai Creek 15. Type Completion (Describe) P~rfnraf_~_d and C~rav~] P~c:.ke8_ Perforations: From To 22 1900-1 930 ', 2005-2032 ' 21~ Speci~avity~l~ ~i~ (G~ ~ ........ 24. Barometric Pressure (Pa),! 5. 0 psia % H2S 0.00 Tubing Data Temp. oF, 39 43 4O 12 42 Pressure psig 512 400 371' 265 256 4= 0'~6" 1 ange Casing Data Pressure psig 25 25 ,, Temp. -$, Duration of Flow Hr. NO. Basic Coefficient (24-Hour) Fb or Fp 20,2!0.88 20,210.88 -V/hwPm 43.79 79.84 psia Pressure Pm 376 332 20,210.88 98.25 325 20,210.88 139.59 217 20,210.88 159.23 184 Flow Temp. Factor Ft 1.0260 1.0260 1.0260 1.0239 1.0270 Gravity Super Comp. Factor Factor Fg Fpv 1 .3316 ll _036 1 ,3316 [1 .032 1 ,3316 1 .031 1 .3316 1 .020 1 .3316 1 .016 Rate of Flow Q, Mc'rd 227~:1 2797.0 3923.5 4471,4.. No~ [ Pr TemperatureT ~. Il'Not calculated., manually. [used Ryder Scott spreads1 3. Itc calculate bc'ttom hole see attached , .eot TF (Measured) Form 10-421 Rev. 5/2000 oressure 664_5 D.~4~ - Critical Pressure Critical Temperature · 342°R CONTINUED ON REVERSE SIDE for Separator Gas Gg 0 R64 _ *Estimated for Flowing Fluid G Submit in duplicab ' ~' STATE OF ALASKA ALASKA O L AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la- TEST: INITIAL [] b. TYPE TEST STABILIZED [] NON STABILIZED [] ANNUAL [] MULTIPOINT:¢~ CONSTANT TIME [] SPECIAL [~] OTHER ISOCHRONAL Bi' 2. Name of Operator 7. Permit to Drill No. Aurora Gas, LLC 167-007 3. Address 8. APl Number 5718 Westheimer,Ste. 1850, Houston, TX 77057 5o-283-20003 4. Surface Location of Well (Governmental Section & State Base Plane Coordinates) 9, Unit or Lease Name 1668 ' FWL, 3369 ' FSL, Sec 20, TIIN,R12W, SM · ~ b'iv~/eq~'~jrrTb e r ........... 3 11. Field and Pool Nicolai Creek 5. Elevation in feet (indicate KB, OF etc.) t 6. Lease Designation and Serial No. +216' (KB) I ADL-63279 12. Completion Date - 13. Total Depth 114. Plugback T.D. 15. Type Completion (Describe) 5/1 4/67 8841 'I 2390' 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To cnn1 /,a~ ~.22 1900-1930',2005-2032' 1~_~/R"/7'' ~ ~/~ 12 6~/~.~ 1'~. T~'g~ ~ze ' V~e~g'h~' )e~'~:)ot, lb. ' ' ' ~.6. ~n InCh~ .... ~et'a't'~ ' - 3-1/2" 9 .. 2. 992 1 808 ' ':~01 -~ P. :~8 ' - 2.302-2338 ', 2360-2380 18. Packer set at ft. 19. GOR cf/bbl. I 20. APl Liquid Hydrocarbons 21. Specific-Gravi{y Flowing fluid (G) 1803' NA I None ~. ~a~o witk water rat~ 22. Producing thru: 23. Reservoir Temp. 80 "%-. ~- 2z~. "'""'~arometric Pressure (Pa),1 5. 0 psia Tbg i~ Csg. [] Reservoir Press.~ 7 6 -k psia @ Datum 1 C) ~ 4 )t"VDSS 25. Length of flow channel (L) J J Pr°var J Meter run /Taps 21 40 ' 21 40 ' .5641 0.22 I 1 . 70 0.00 4= O ~6" Flange 26. Flow Data ! Tubing Data Casing Data I ~ I Pr°ve{ Mtr RUQt')ek'e' Pressure Diff' T'eI~P' Pressure Tomp' Pressure ToI~p' Durati°n °fo. SizeLine (in.) X SizeOrifice(in.) psig hvv · psig o F, psig . . FlOWHr. 4,.026 2.0 361 5,1 34 512 39 25 - I 2. I 4, 02~' 2.0 31 7 I 9, ........ 2 34 400 43 ~ - .2.. 5 I 2.0 0 7 37 . 40 25 - ,, 14 l4'026 2.0 202 '89.8 36 ' '~6~ 12 25 - t _~ [4~026 ' 2.0' 169' 'j, 37.8~ 33 256 42 ;~5 - .10-5'i-_.~'..,-- Pressure Factor Factor Factor Rate of Flow (24-Hour) hwPm Prn Fpv Q, Mcfd No. Fb or Fp Ft Fg I.. 120,210.88 43 79 376 1.0260 1.3316 '1.036 125~.6 ' 120'210 88 79.84 332 1.0260 1.3316 11.032 2275:1 · 20,210 88 98.25 325 1.0260 1 .3316 1 i 20,210 88 139.59 217 1.0239 I 1.3316 I1 ,020 3923.5 20,210 88 159.23 184 1.0270 I I .3316 11-016 4471 .4 for Separator for Flowing Temperature Pr T Tr z (Measured) Gas Fluid .4o. Gg G I. ('Not calculate~, manually- . 0_-564 Z /used Ryder SC°tt spreadsl~eet 664..5 ~s~ .. ~, It© calcUlate' bcttom hole pressure- criticalPressure ~ t see attached CriticalTemporaturo342o~_ Form 10-421 Rev. 5/2000 CONTINUED ON REVERSE SIDE *Es timated Submit in duplicate Po 828 psia Pc2 685,584 Pf' No. Pt Pt2 Pc2-Pt2 Pw PW2 Pc2-Pw2 Ps ~s~ P~ I. 527 277,729 407,85~ .... 593 351 , 340 404,1 00 2. 4i5 172~225 513,35~ I 479 229,373 526,067 3. 386 148,996 536,5.8~ 4. 288 82.944 602.64f 3~ 5. 271 73.441 612,14= 25. 1.0 AOF (Mcfd) 5 2 9 7 n Remarks:Ps and Pf values were calculated from measured Pt and Pc value using Ryder Scott spreadsheet (macro)-a copy of the printout is attached. ~h. points plot so that n>l.0,so AOF is calculated by Ryder Scott macro using n=l .0 through last flow point,as per Manual of Back-Pressuring Testing of I hereby cedi~ that~he foregoi~true and correct to the best of my knowledge Gas Wel lsd, Signed ~ . Title Vice President Date 4/26/01 AOF Fb Fp Fg Fpv Ft · ~. G Gg GOR hw H L n Pa PC Pf Pm Pr Ps Pt Pvv Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. ,,, Basic orifice factor Mcfd/-% hwPm Basic critical flow prover or positive choke factor Mcfdlpsia Specific gravity factor, dimension_less Super compressibility factor=-, 11Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=l.000), dimensionless Specific Gravity of separator gas (air=l.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water ' Vertical depth corresponding to L, feet (TVID) Length of flow channel, feet (MID) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.6,5 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. POINT NO. Test ~ FLOWING ..(A~..~). ........... BCm ~ ..........FTP, Psia Wi'fl', °F: BHP, Psia COMMENT , .... . ,., , ., ,, ,~., , , . _ . : .... *... - .. .... smfl'..IM 0 0 0 828 61 8eo SIBHP I t,263 0 163 527 39 693 2 '2,,~r6 0 211 4t6 43 47'0 3 .. . ~797 0 144 386 40 43T 4 3~ 0 168 288 17 366 6 4,471 O 134 271 42 343 Exteltded Petroleum Engineers 1100 Louisiana, Suite 3800 Houston, Texas 77002.6218 Tel: ('/13)661..6101 Fax: (713) 6614)849 AURORA GAS, LLC NICOLAI CREEK UNIT NO. 3 Unique Well ID Well Operator Field Formation Pool Aurora Nicolai Creek U. Tyonek Start Test [ 2/23/2001 yyyy/mm/dd Start Test ' 13:44:26 hh:mm:ss Remarks 80-3020 80-3020 80-3020 80-3020 80-3020 Time Temp. Pres. Date CIk Time hr °F psi(a) yyyy/mm/dc hh:mm:ss 0 33.56 15.84 2/23/2001 13:44:26 0.0036 33.56 15.85 2/23/2001 13:44:39 0.0233 33.58 329.48 2/23/2001 13:45:50 0.3303 33.81 328.1 2/23/2001 14:04:16 0.6264 33.77 335.61 2/23/2001 14:22:02 1.1119 34.01 334.97 2/23/2001 14:51:09 1.395 34.45 336.91 2/23/2001 15:08:08 1.9394 35,57 336,78 2/23/2001 15:40:48 2.3156 36.28 258.57 2/23/2001 16:03:23 2.7922 36.28 258.4 2/23/2001 16:31:58 3.6978 37.11 254.27 2/23/2001 17:26:19 4.24 34.03 273 2/23/2001 17:58:50 5.0778 28.45 21.64 2/23/2001 18:49:07 5.1736 27.87 700.83 2/23/2001 18:54:51 5.1747 22.01 16.62 2/23/2001 18:54:55 5.1758 20.68 -163.51 2/23/2001 18:54:59 5,1769 19.59 -335.03 2/23/200t 18:55:03 5.1781 18.69 -400 2/23/2001 18:55:08 5.1792 17.92 -400 2/23/2001 18:55:12 5.1803 17.18 -400 2/23/2001 18:55:16 5.1814 16.58 -400 2/23/2001 18:55:20 5.1825 16.12 -400 2/23/2001 18:55:23 5.1836 15.53 -400 2/23/2001 18:55:27 5.1847 14.96 -400 2/23/2001 18:55:31 5.1858 14.38 -400 2/23/2001 18:55:35 5.1869 4.5 16.13 2/23/2001 18:55:39 5.1881 3.68 16.09 2/23/2001 18:55:44 5.1892 2,8 16.07 2/23/2001 18:55:48 18.8608 7.67 16.64 2/24/2001 8:36:05 18.8725 7.82 16.64 2/24/2001 8:36:47 18.9089 8.29 16.67 2/24/2001 8:38:59 19.0428 9.63 16.67 2/24/2001 8:47:01 19.1914 10.24 16.61 2/24/2001 8:55:56 19.6506 9.79 16.43 2/24/2001 9:23:29 20.0386 20.25 20.3575 20.4281 20.5664 20.9611 21.1633 21.1967 21.2986 21.3361 _21.4764 21.595 21.9072 22.2806 22.4553 22.8686 23.1461 23.4094 23.4872 23.6719 23.7836 24.0956 24.425 24.71 O6 24.9314 25.1856 25.5778 25.6722 25.9681 26.1936 26.4622 26.78 26.96 27.1919 27.4442 27.6739 27.9517 28.1653 28.3344 28.3669 28.8906 29.2453 29.5539 29.8758 30.2128 31.1219 31.1231 32.14O8 32.1419 32.1431 9.07 8,83 8.87 8.97 9.43 12.16 14.4 14.86 16.45 17.16 20.32 22.69 27.06 31.1 32.73 35.7 37.15 38.16 38.32 38.54 38.66 38.99 39.1 39.38 39.62 40.33 41.27 41.46 42.38 43,21 43.36 43.62 43.96 44.52 44,76 44.06 42.11 40.15 38.48 38.15 32.75 29.28 26.48 23.81 21.23 15.66 12.31 12.27 11.37 10.56 16.34 2/24/2001 9:46:45 16.37 2/24/2001 9:59:27 16.43 2/24/2001 10:05:54 16.48 2/24/2001 10:10:08 16.61 2/24/2001 10:18:26 17 2/24/2001 10:42:06 813.34 2/24/2001 10:54:14 .824.2 2/24/2001 10:56:15 823.61 2/24/2001 11:02:21 823.25 2/24/2001 11:04:36 822.1 2/24/2001 11:13:02 699.92 2/24/2001 11:20:09 527.25 2/24/2001 11:38:52 512.53 2/24/2001 12:01:17 514.17 2/24/2001 12:11:46 513.27 2/24/2001 12:36:33 515.61 2/24/2001 t2:53:12 523.61 2/24/2001 13:09:00 532 2/24/2001 13:13:40 525.54 2/24/2001 13:24:45 ----- 445.26 212412001 13:31:27 443.81 2/24/2001 13:50:11 437.59 2/24/2001 14:09:56 453.67 212412001 14:27:05 453.43 212412001 14:40:20 455.75 2/24/2001 14:55:35 456.09 212412001 15:19:07 406.16 2/24/2001 15:24:46 411.23 2/24/2001 15:42:32 413.12 2/24/2001 15:56:03 366.92 2/24/2001 16:12:10 375 2/24/2001 16:31:15 382.04 2/24/2001 16:42:03 386.01 2/24/2001 16:55:57 381.96 2/24/2001 17:11:06 382.41 2/24/2001 17:24:53 385.2 2/24/2001 17:41:33 386.38 2/24/2001 17:54:22,¢__ 301.2 2/24/2001 18:04:30 ~' .... ~)/~ ~/~'~ ~ 273.38 2/24/2001 18:06:27 277.11 2/24/2001 18:37:53 280.82 2/24/2001 18:59:10 280.81 2/24/2001 19:17:41 283.21 2/24/2001 19:36:59 280.75 2/24/2001 19:57:13 280.12 2/24/2001 20:51:45 281.04 2/24/2001 20:51:50 281.3 2/24/2001 21:52:53 88.81 2/24/2001 21:52:57 "~ ~'~-,¢e. 7~ ,fJCo~/~ ,,--- -//~w~z./'rd- ,.,-3//~ -94.3 2/24/2001 21:53:02 ,.,/ 32.1442 35.1517 35.1528 36.1894 36.1997 37.1669 38.1414 38.1469 38.1481 39.1767 39.6297 39.6353 39.6975 40.2061 40.2119 40.2181 40.2261 41.2083 41.2186 41.2258 42.1856 43.1247 43.1317 43.1439 44.0708 44.2147 44.2556 44.6786 44.7447 44.7733 44.7906 44.8067 44.8236 44.84 44.8569 44.8761 44.8906 44.9069 44.9236 44.9631 45.0233 45.0475 45.1089 45.1733 45.2578 45.3442 45.4233 45.6775 45.9228 46.1742 9.42 10.17 13.26 13.37 13.4 15.62 17.16 17.17 17.19 17.68 17.44 17.44 17.41 17.12 17.12 17.12 17.11 16.81 16.81 16.81 16.77 16.9 16.9 16.91 40.25 44.41 44.92 41.65 40.76 40.4 40.19 39.98 39.77 39.56 39.36 39.13 38.95 38.76 38.57 38.12 37.45 37.19 36.55 35.93 35.17 34.45 33.85 32.14 30.73 29.58 -269.01 2/24/2001 21:53:06 285.92 2/25/2001 289.45 2/25/2001 289.76 2/25/2001 289.73 2/25/2001 290.48 212512001 290.51 2/25/2001 290.52 2/25/2001 98.33 212512001 289.26 2/2512001 288.97 2/25/2001 288.98 212512001 289 212512001 288.83 2/25/2001 288.87 2/25/2001 288.84 2/25/2001 288.83 212512001 288.76 212512001 288.85 2/25/2001 288.81 2/25/2001 289.1 212512001 289.05 212512001 288.98 2/2512001 289.04 2/25/2001 271.63 212512001 270.53 212512001 271.72 212512001 0:53:33 0:53:37 1:55:48 1:56:25 2:54:27 3:52:56 3:53:15 3:53:20 --~' 4:55:03 5:22:13 5:22:34 5:26:17 5:56:48 5:57:09 5:57:32 5:58:00 6:56:56 6:57:33 6:57:59 7:55:35 8:51:55 8:52:21 8:53:05 9:48:41 9:57:t9 9:59:47 271.48 2/25/2001 10:25:09._.__ 321.41 2/25/2001 10:29:07 606.86 2/25/2001 10:30:50 667.36 2/25/2001 10:31:53 691.72 2/25/2001 10:32:51 706.12 2/25/2001 10:33:51 715.31 2/25/2001 10:34:51 721.71 2/25/2001 10:35:51 727.53 212512001 10:37:00 731.39 212512001 10:37:53 734.74 2/25/2001 10:38:51 737.84 2/25/2001 10:39:51 737.89 2/25/2001 10:42:14 747.74 2/25/2001 10:45:50 748.37 2/25/2001 10:47:18 754.23 2/25/2001 10:50:59 758.03 212512001 10:54:50 762.28 212512001 10:59:55 761.12 2/25/2001 11:05:06 762.1 212512001 11:09:50 760 212512001 11:25:06 768.81 212512001 11:39:49 770.27 2/25/2001 11:54:54 46.4275 46.4356 46.5553 46.9225 47.4572 47.9722 47.9839 48.0931 48.0942 49.5086 49.5389 49.7197 49.7833 50.4258 51.0597 51.4322 52.0372 52.0383 53.3044 53.3056 53.3067 53.3078 53.3089 53.31 53.3111 53.3122 53.3133 53.3144 53.3156 53.3167 53.3178 53.3189 53.32 53.3211 68.9344 69.8103 70.1511 71.1797 71.1808 72.4231 73.4328 74.42 99.1781 99.215 28.67 28.64 28.25 27.25 26.37 25.61 25.59 25.37 47.42 59.96 60.83 63.04 62.51 48.46 38.48 34.76 30.35 29.01 26.19 24.86 24.36 24.11 24.63 25.04 26.5 29.5 31.49 32.78 33.32 33.07 32.32 31.91 31.51 32.87 37.32 44.5 43.82 43.75 45.63 45.98 46.36 44.41 50.88 50.91 757.97 757.5 789.89 792.53 794.67 796.18 796.41 797.08 15.06 14.38 793.22 16.05 800.29 801.25 8O2.64 803.44 804.07 584.68 805.96 807.29 808.71 809.74 810.95 811.98 812.45 812.97 813.72 814.62 815.59 816.48 817.64 818.47 819.42 820.02 820.13 820.81 820.95 821.52 822 822.09 822.38 822.79 15.04 828.11 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/25/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/26/2001 2/27/2001 2/27/2001 12:10:06 12:10:35 12:17:46 12:39:48 13:11:52 13:42:46 13:43:29 13:50:02 13:50:06 15:14:57 15:16:47 15:27:37 15:31:26 16:09:59 16:48:01 17:10:22 17:46:40 17:46:44 19:02:42 19:02:47 19:02:51 19:02:55 19:02:59 19:03:02 19:03:06 19:03:10 19:03:14 19:03:18 19:03:23 19:03:27 19:03:31 19:03:35 19:03:39 19:03:42 10:40:30 11:33:04 11:53:30 12:55:13 12:55:17 14:09:50 15:10:25 16:09:38.....~' 16:55:o8 16:57:20 AURORA GAS, LLC NICOLAI CREEK UNIT NO. 3 WELL TEST FIELD RECORD START: 2/23/01 E N D: 2/28/2001 DATE DELTA T TBG P L-10 Pu Q, mcfpd MTR P MTR T WTR MTR WTR BPH TIME hr (psia)..L-10...Hu...WHT.,dF psig .... deg.F. CUM,.bblGWR:scflbbl Q (mcfpd)=C'*M*Hu*Pu*24/1000, M=.01 *SQR(RuRp) C'=Fb*Ftf*Fg 4-inch meter run, 4.026" ID. Rp (psi)= 1000 Rh(in wtr)= 100 1.5" orifice Fb= 460.79 M= 3.162278 Fg= 1.313064 Friday, February 23, 2001 Ft= 1.025978 C'= 620.765 0830 Pollard Wireline ready-Start to swab--no pressure on well, FL @ surface, test lines frozen. 0930 Thaw lines and start to swab: 2 runs to 150', well kicked off, flowing diesel from tree. 1015 Leak at flange/3" crossover. SI well and tighten-leak stopped 1030 SITP= 530 psi. Open well and flowed through test separator 48/64+40/64" chokes 1100 320 1130 300 1983 250 34 9.9 1200 By pass sep to unload 1230 200 70 psi drop across chokes (45/64 + 36/64") 1300 Catch water sample: lots of dark gray fines (mud?) 1140 Install quartz crystal pressure monitor at inlet to choke skid. Well back thru sep. Rig down Pollard Wireline 1430 328 5.43 2377.3 280 15.5 9.3 1500 336 5.4 2366.0 280 34 20.2 9.3 1530 Open to 2 X 48/64" chokes 336 5.47 2410.3 285 35.5 26.1 9.35 155O Reduce separator pressure to 180 psi. 12 9.4 10488 Change orifice plate to 2-1/4".Fb= 11.8 8511 1089.9 C'= 1468.287 1620 258 4.63 2631.5 200 34.3 9.84 5.1 11143 1650 Both chokes--Open 1720 Replace flow recorder 1740 280 Rp=- 1500 3.7 3570.7 5 3.7 3499.3 4.9 Ck Pu, P= Shut in for buildup. 1810 1830 270 (Gauge) 500 " 660 " 680 " 735 " 870 (Gauge freezing?) 857 1831.5 0.025 1834 O. 066667 1835 0.083333 1840 O. 333333 2140 3.166667 2210 3.666667 Rh= 200 M= 5.477225575 200 35 40.4 4.59 32439 210 43.5 6.2 190.95 23517 46.7 9.70 See output from Surface Pressure Monitor for more accurate buildup pressures. DATE DELTA T TBG P TIME hr Calc BHP 1110 1115 1130 1150 1205 1230 1245 1300 MULTIPOINT TEST L-10 Pu Q, mcfpd MTR P L-lO HU ..~HT, d F Calc Pf MTR T VVTR MTR WTR, bph de~l F CUM, bbl GWR:scflbb! , Saturday, February 24, 2001 (Tbg pressure measured wi quartz crystal monitor) 0800 13.5 1000 +8 deg F Frozen-not accurate-. Thaw out lines. 1100 16.5 823 psia +16 deg F (Monitor-- Gauge reading of SITP=800 psi) 873 Calc BHP, psia (Ryder-Scott program) Change to 2" orifice plate. Fb= 842.12 C'= 1134.483 Open on 16/64" choke 4.4 280 46.7 Ck Pu, P= 276 Open to 22/64" choke 527 4.7 1401.8 310 50 2 514 4.8 1288.5 340 40 48.7 2.4 1.8 22370 510 4.9 1169.2 345 38 50.6 7.6 1.6 6410 508 5 1193.1 350 36 54.5 9.36 1.6 5311 518 5 1193.1 56.8 9.2 1.6 5403 523 5 1193.1 350 35 58.8 8 1.6 6214 1305 1315 1318 1335 1400 1415 1430 1445 15O5 1510 1515 1530 528 1193.1 527 5 1193.1 355 34 603 1.6 38.5 552 Opento 32/64"choke Stop methanoli~e~ion at manifold. 447 5.2 1706.1 380 35 2.2 Ck Pu, P= 391.2 439 5.1 1749.3 380 35 2.3 5.1 2.3 5.1 2.3 5.2 2.3 5.2 2.5 452 1749.3 390 35 454 1749.3 400 35 457 1783.6 400 35 456 1938.7 400 35 527 41.2 478 Reduce separatorpressureto 300 psi 408 4.6 2332.4 300 34 412 4'15 486 Open choke to 48/64", 367 3.4 4.7 2102.8 320 3 4.7 2172.8 325 3.1 43.2 375 adjust separator pressure to 305 psi. 4.55 2408.9 305 3.55 4.6 2469.6 315 3.6 34 34 34 35 60.5 64.6 68.6 70.9 73.4 75.3 78.1 81.9 84.1 86.6 89.9 1545 1600 1620 6.8 7310 12.3 5779 9.6 7593 9.2 7923 10 7289 7.6 9779 8.4 9617 9.12 9607 8.8 10288 10 10037 10 10290 DATE DELTAT TBG P L-10 Pu TIME hr Calc BHP L-10 Hu 1630 381 4.6 3.6 1645 386 4.65 3.6 1700 381 4.65 3.7 1715 382 4.65 3.75 1730 385 4.65 3.8 1745 386 4.65 442 3.85 Open chokes to 2 X 32/64" 1800 275 3.75 5.45 1830 276 3.75 5.55 1845 280 3.8 5.6 1905 280 3.8 5.7 1930 283 3.7 6.2 1945 279 3.7 6.2 2O45 279 3.8 6.35 2145 280 3.8 6.5 2245 280 3.8 6.65 2345 280 3.8 354 6.7 Reduce separator pressure to 200 Sunday, Febma~ 25,2001 O045 285 3.6 7.2 0145 288 3.7 7.2 0245 289 3.7 7.3 0345 288 3.7 7.3 0445 288 3.75 7.3 0510 Open to 2 X 48/64" chokes Q, mcfpd MTR P WHT, d ,F ............ psig 2469.6 315 2496.5 320 2565.8 320 2600.5 310 2635.2 320 2669.8 320 40.1 404 Thento 2 X 40/64" 3O47.9 3103.8 210 3173.5 210 3230.2 215 3421.1 210 3421.1 20O 3598.5 220 3683.6 220 3768.6 220 3796.9 230 12.2 294 psi(was controlling flow) 3865.5 200 3972.9 200 4028.0 200 4028.0 200 4082,5 210 MTR T WTR MTR WTR, bph de9 F CUM, bbl GWR:$c~bbl 35 91.5 9.6 10719 34 93.4 7.6 13687 35 95.1 6.8 15722 35 97.8 10.8 10033 35 99.6 7.2 15250 34 101.1 6 18540 35 109.1 10.7 12124 35 112 11.6 11399 35 114.5 7.5 17946 35 117.8 7.92 17998 35 119.9 8.4 16970 36 127.2 7.3 20540 36 134.4 7.2 21317 36 141.1 6.7 23436 36 147.7 6.6 23970 36 154.6 6.9 23342 36 161.1 6.5 25467 35 166.9 5,8 28937 36 172.7 5.8 28937 36 178.7 6 28351 DATE TIME O545 0645 O745 0845 0945 1015 DELTA T TBG P L-10 Pu Q, mcfpd MTR P hr Calc BHP L-10 Hu ,WHT, d F psig 288 3.8 4165.2 210 7.35 288 3.8 7.35 288 3.8 7.4 288 3.8 361 7.4 MTR T WTR MTR WTR BPH de9 F CUM, bbl GWR:scflbbl 35 4165.2 210 35 4193.6 210 35 4193.6 210 34 303 Drop separator pressure to 180 psi (was controlling flow) 271 3.5 4332.3 180 8.3 271 3.5 4332.3 180 349 8.3 41.6 284 184.6 5.9 29416 190.2 5.6 30991 195.5 5.3 32968 200.9 5.4 32358 34 206.1 5.2 34714 33 208.9 5.6 32234 TIME 1020 1021 1022 1023 1024 1025 1026 1027 1028 1029 1030 1035 1037 1041 1045 1050 1055 1100 1115 1130 1145 1200 DELTA T SITP PJS BHP hr psia Ca,lc, ps!,a Shut in well for pressure buildup. 0.01667 594 628 0.03333 663 701 0.05000 690 730 0.06667 704 745 0.08333 714 755 0.10000 721 763 0.11667 727 769 0.13333 731 773 0.15000 735 778 0.16667 737 780 Opento repressure separatorfor 0.25000 747 0.28333 748 0.35000 754 0.41667 758 0.50000 761 0.58333 761 0.66667 762 0.91667 760 1.16667 768 1.41667 770 1.66667 757 1208 1230 1302 1332 1342 1507 1521 Thaw monitor line 1.80000 789 2.16667 791 2.70000 794 3.20000 795 3.36667 796 4.78300 794 5.01667 800 Open 2nd 791 798 802 806 807 805 813 816 WH TEMP Calc BHP ........ de.g F =Pw*e**f (f=GD/53.34TI (After $1 1 choke, FFTP=290 psia and building). 40.4 622 40.4 695 40.4 723 40.4 738 40.4 748 40.4 755 40.4 762 40.4 766 40.4 770 40.4 772 about1 min., SITP after=736 psia time to pressure sep 38 784 36 790 35.9 794 35 798 34 798 33.7 799 32 797 32 805 29.6 807 24 Freezing off? (to 100 psi) 836 24 828 838 23.7 830 841 26.2 833 642 freezing 844Questionable, ~eezing Questionable, freezing-blow out monitorline 848 28 839 1600 5.66667 800 28 839 1639 6.31667 801 849 31 840 1700 6.66667 802 850 32 841 1738 7.30000 803 851 30 842 1853 8.55000 805 853 26 844 Monday, February 26, 2001 1030 24.16667 819 867 37 858 1144 25.40000 820 868 43 859 1245 26.41667 820 43 859 1400 27.66667 821 869 46 860 1600 29.66667 822 870 46 861 Tuesday, February 27, 2001 1645 54.41700 828 876 51 867 Removed monitor and secured well (closed swab and master valves). NOTES: "R/S BHP Calc" and "Calc BHP" are calculated from SITP using Ryder Scott free downloaded Flowing Gas Analysis software. ~a~ 09 O! 03:39p P~ro]eum Services ?~328-2197 Aurora Gas, LLC Nicolai Creek Unit #3 RFL 2001-015 Composition of Field Gas Cyl. #EI.447 ( From Chromatographic Technique ) ,, Liq Component Mol % GPM MW Dens (~..m/cc) Hydrogen Sulfide 0.00 Carbon Dioxide 0.22 44.010 .8172 Nitrogen 1.70 28.013 .8086 Metllane 97.90 16.043 .2997 Ethane 0.18 .048 30.070 .3562 Propane 0.00 iso-Butane 0.00 n-Butane 0.00 iso-Pentane 0.00 n-Pentane 0.00 Hexanes 0.00 Heptanes plus 0.00 _..TOta,s ........... 1"400.001 0.0~ I ' I Properties of Plus Fractions Liq Component Mol % MW Dens APl (gm/cc) Gravity ,, Sampling Conditions 400 psig 35 OF Sample Characteristics This is Core Lab sample number 204 Critical Pressure (psia) .............................. 664.5 Critical Temperature (°R) ........................... 341.9 Average Molecular Weight ......................... 16.33 Calculated Gas Gravity (air = 1.000) ......... 0.564 Gas Gravity Factor, Fg ................................................ 1.3316 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0335 Gas Z-Factor at sampling conditions *. .......................... 0.936 at 14.65 psia and 60 °F Heating Value, Btu/scf dry gas Gross ...................................................... 989 Air Content, mol % Air Oxygen ................................................. 0.12 Air Nitrogen ................................................ 0.43 Total Air Content ........................................ 0.55 * From: Standing, M.B., "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas),1977, 8th Edition, Appendix I1. 3/9/01 2:23 PM Page 2 of 2 CORE LABORATORIES Mar O9 O1 05: 5~p P~oleum Services 71~.,~32B-2197 p.2 Aurora Gas, LLC Nicolai Creek Unit #3 RFL 20014)15 Composition of Field Gas Cyl. #CLH 315 ( From Chromatographic Technique } ..... Li~" Component Mol % GPM MW Dens (gm/cc) ,,.... ,, ,, Hydrogen Sulfide 0.00 Carbon Dioxide 0.23 4,1.010 .8172 Nitrogen 1.b'5 28.013 .8086 Methane 97.92 16.043 .2997 Ethane 0.20 .053 30.070 .3562 Propane 0.00 iso-Butane 0.00 n-Butane 0.00 iso-Pentane 0.00 n-Pentane 0.00 Hexanes 0.00 Heptanes plus 0.00 Tot, I; ........... '-' ! ~0o.0o ! 01~53 i ..... Il Properties of Plus Fractions Liq Component Mol % MW Dens APl (gm/cc) Gravity ,, ,,, Sampling Conditions 210 psig 35 OF Sample Characteristics This is Core Lab sample number 205 Cdtlcal Pressure (psia) .............................. 664.6 Critical Temperature (°R) .......................... 342.0 Average Molecular Weight ......................... 16.33 Calculated Gas Gravity (air = 1.000) ......... 0.564 Gas Gravity Factor, Fg ................................................ 1.3316 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0169 Gas Z-Factor at sampling conditions '. .......................... 0.967 at 14.66 psia and 60 °F Heating Value, Btu/scl dry gas Gross ...................................................... 989 Air Content, mol % Air Oxygen ................................................. 0.02 Air Nitrogen ................................................ 0.07 Total Air Content ........................................ 0.08 * From: Standing, M.B., "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas),1977, 8th Edition, Appendix I1. 3/9/01 4:3§ PM Page 2 of 2 CORE LABORATORIES ,/ ,:NCU#3 Gas Production Test Commencement] Subject: [Fwd: NCU#3 Gas Production Test Commencement] Date: Wed, 21 Feb 2001 12:20:40 -0900 From: Tom Maunder <tom_maunder~admin.statc.ak.us> To: Wendy Mahan <wendy_mahan~admin. state.ak.us> Subject: Re: NCU#3 Gas Production Test Commencement Date: Wed, 21 Feb 2001 10:31:39-0900 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Bill Penrose <bill~fairweather. com> CC: John Hartz <jack_hartz~admin. state.ak.us>, Bob Crandall <bob_crandall~admin.state.ak.us>, Julie Heusser <julie_heusser~admin.state.ak.us> Bill, Thanks for the notification. We look forward to reviewing the test results. Tom Bill Penrose wrote: > Tom, > Per our telephone discussion this morning, please consider this Aw'ora Gas' > nott~'ication that it will soon commence the testingjbr gas potential of the > Nico[ai Oeek #3 well. l~. anticipate unloading the well on the afternoon of > February 22., 2001 and commencing the gas test thejbllowing day. > Regards, > Bill Tom Maunder <tom maunder@~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 2/21/01 4:13 PM E & P SERVICES, INC. 7-oo-1 January 26, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Nicolai Creek Unit #3 Well Recompletion Report Dear Commissioner Heusser, Attached find Aurora Gas, LLC's Well Recompletion Report and Log for the recently completed Nicolai Creek Unit #3 Workover. Included are the following: · Well Completion or Recompletion Report and Log (Form 407) · Workover Operations Sunmmry · Diskette containing P/Dt~files of logs run in the well during the workover This well will be tested prior to being placed on production. However the timing of the test is uncertain at this time. Negotiations are currently underway with the owners of portable testing equipment and the timing of its use will depend on its availability. The testing of this well was approved in Aurora's Application for Sundry Approval for the workover (approved 10/5/00) and the Commission will be informed prior the test's commencement. If you have any questions or require additional information, please contact me at (907) 258-3446. Sincerely, FAI~ E&P SERVICES, INC. Bill Penrose Sr. Project Manager enclosures RECEIVED JAN 3 ! 2001 Alaska Oil & Gas Cons. Commission Anchorage cc: Mr. Ed Jones- Aurora Gas 715 L Street Anchorage, Alaska 99501 ORIGINAL (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. 1. Status of Well Classification of Service Well OIL [] GAS ~] SUSPENDED [] ABANDONED [] SERVICE [] _ .,, 2. Name of Operator 7. Permit Number Aurora Gas, LLC 167-007 3. Address 8. APl Number 5718 Westheimer, Ste. 1850, Houston, TX 77057 50-283-20003 4. Location of well at surface 9. Unit or Lease Name 1668' FWL, FSL 3369', Sec. 20, TllN, R12W, SM Nicolai Creek Unit At Top Producing Interval ' 10. Well Number · (@1900') 1662' FWL, 3366' FSL, Sec. 20, TllN, R12W, SM 3 At Total Depth 11. Field and Pool (@8841') 1290' FWL, 3035FSL, Sec. 20, TllN, R12W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. micolai Creek ~-216' KBI A-034161 12. Date Spudded 13. Date T.D. Reached '14.-Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/6/00 N/A-Workover ~2/25/00 /~I N/A feet MSL ] _ 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8841' MD/TVD 2390' MD/TVD. IYES [] NO ~ N/A feet MD N/A 22. Type Electric or Other Logs Run GR/CCL Correlation log: perforatimg log: plug .~ett~ng re~ord .... 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" - - 19 ' 282 ' 26" 720_=x -0 .... 1R 3/8" 54.5 J-55 ]9' 200!' 17 !/2'~ !7705x 7" 29 N-80 !941'' 2522' 9 7/8" 2205x -0- . , ,,, 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) 1900'-1930' 7" HSD, 18SPF ~ 1 /?" 2385' 1803' 2005'-2032' 4 1/2"HSD, 12SPF ... 26. AC~D, FRACTURE, cEMENT SQUEEZE, ET'c.' 2201'-2238' 4 1/2"HSD, 12SPF ... 2302'-2328' 4 1/2"HSD, 12SPF DEPTH INTERVAL (MD) AMOUNT & KIN'D OF MATERIAL USED ,.. 2360'-2380' 4 1/2"HSD, 12SPF 1835'-2390' gravel packed w/ 29;744 of 12/. 20 .. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I N/A-Test to be performed at a later date. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'~OILRATIO TEST PERIOD I~ I '" Flow Tubing Casing Pressure CALCULATED I~' OIL-BIlL GAS-MCF WATER-BBL OIL GRAVITY-APl (co~r) ..... Press. 24-HOUR RATE -~ 28. CORE DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED N/A- Cased-hole Workover JAN 3 I Z001 Alaska Oil & Gas Cons, Commission Anchorage Form 10-407 0 R ! G I ~IAI Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 3O. NAME GEOLOGICMARKEHS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A - Cased-hole Workover 31. LIST OF ATTACHMENTS 32. I hereby certify that the fo,'egoing is true and correct to the best of my knowledge ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log o'n 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Aurora Gas, LLC Nicolai Creek Unit #3 Workover to Return to Production Operations Summary 11/30/00 Living accommodations (M/V Arctic Wolf) arrived on beach at Shirleyville. Drilling crew arrived, underwent accommodation vessel orientation. Prepared rig components for moving out of Tyonek Contractors' yard to Nicolai Creek Unit #3 location. 12/1/00 PBTD: 2,478', Mud Wt.' 9.2 ppg Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/2/00 PBTD: 2,478', Mud Wt.: 9.2 ppg Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/3/00 PBTD: 2,478', Mud Wt.' 9.2 ppg Transport rig componems from Tyonek Contractors' yard to NCU #3. Rig up. 12/4/00 PBTD: 2,478', Mud Wt.: 9.2 ppg Transport rig componems from Tyonek Contractors' yard to NCU #3. Rig up. 12/5/00 PBTD: 2,478', Mud Wt.' 9.2 ppg Transport rig components from Tyonek Contractors' yard to NCU #3. BPV. Install 12/6/00 PBTD: 2,478', Mud Wt.: 9.2 ppg Finish rigging up. Rig accepted at 1400 hrs. N/D tree, N/U BOPs. 12/7/00 PBTD: 2,478', Mud Wt.: 9.2 ppg Finish N/U BOPs and flowline. Test BOPE to 250/2,000 psi. Test witness waived by J. Spaulding of AOGCC (Anchorage weather prevented flying). RECEIVED J/I.N ~ 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Aurora Gas, LLC NCU#3 Workover 12/8/00 PBTD: 2,478', Mud Wt.: 9.2 ppg Test accumulator. N/U and thaw trip tank. Pull BPV. Back out lock downs on tbg and unseat tbg hanger. Circulate well. 12/9/00 PBTD: 2,478', Mud Wt.: 9.5 ppg Circulate well. POH w/2-7/8" tbg. Change pipe rams to 3-1/2". P/U cleanout bit, DC's and 3-1/2" tbg and RIH. 12/10/00 PBTD: 2,478', Mud Wt.: 9.7 ppg RIH w/3-1/2" tbg to 2007'. Wash out fill f/2007' to 2053'. 12/11/00 PBTD: 2,478', Mud Wt.: 9.4 ppg Wash fill to 2462' while circulating and sweeping hole. 12/12/00 PBTD: 2,478', Mud Wt.: 9.4 ppg (Waiting on packer) Circulate well. POH. Repair hydraulic leak. M/U 7" casing scraper, RIH, pump sweep around. 12/13/00 PBTD: 2,478', Mud Wt.: 9.3 ppg Circulate well while waiting on packer. 12/14/00 PBTD: 2,478', Mud Wt.: 9.3 ppg Circulate well while waiting on packer. plug. WOC. Informed packer will not make it. Set cement 12/15/00 PBTD: 2,478', Mud Wt.: 9.3 ppg Test cmt plug. N/D BOP stack. N/D tbg spool. N/U and test new tbg spool. 12/16/00 PBTD: 2,478', Mud Wt.: 9.3 ppg N/U BOP stack. Test same to 25./2000 psi Witnessed by AOGCC Inspector Jeff Jones. Rig operations shut down when AOGCC inspector noticed lack of pit level and flow show indicators (PVT system). 12/17/00 PBTD: 2,478', Mud Wt.: 9.3 ppg Wait on PVT system. Install and calibrate PVT systerr[ RECEIVED JAN 3 1~. ZOO1 Alaska Oil 8, Gas Cons. Commission Anchorage Aurora Gas, LLC NCU#3 Workover RECEIVED JAN 3 1 ZOO1 Alaska Oil & Gas Cons. Commission 12/18/00 Anchorage PBTD: 2,478', Mud Wt.: 9.1 ppg P/U bit and 7" csg scraper. Drill up cement plug. RIH, adding 13-3/8" scraper to string. Circulate and condition well. 12/19/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Circulate 17 bbls viscous mud sweep. Circulate 17 bbls viscous KC1 sweep. Circulate 89 bbls caustic sweep. Displace well to 3% KC1 brine and filter same. 12/20/00 PBTD: 2,478', Mud Wt.: 8.6 ppg POH, L/D kelly and csg scrapers. R/U wireline, nm GR/CCL correlation log from 2,453' to 1,400'. P/U 4" perforating guns and perforate 7" liner (4-1/2" HSD guns, 12 spf, 60° phasing) 2360'-2380', 2308'-2328'. 12/21/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Perforate 7" liner (4-1/2" HSD guns, 12 spf, 60° phasing) 2302'-2308', 2218'-2238', 2201'-2218', 2012'-2032', 2005'-2012'. R/D wireline. M/U 7" perforating gun ( 7" HSP gun, 18 spf) on 3-1/2" tubing and RIH. Space out and perforate 13-3/8" casing 1900'- 1930'. POH and L/D guns. RIH w/6" bit and 7" and 13-3/8" csg scrapers. Circulate well, pump hi-vis sweep, filter brine. 12/22/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Circulate and filter brine. POH and L/D scrapers and bit. RfU wireline, set Baker bridge plug in 7" liner at 2,390', POH and R/D wireline. L/D drill collars out of derrick and prepare to mn wire-wrapped screen. 12/23/00 PBTD: 2,478', Mud Wt.: 8.6 ppg RIH w/ wire-wrapped screen and Baker Model DB packer, wash string and gravel packing tools. Set 3-1/2", 9.2#, SLHT wire wrapped screen from 1,933' to 2,384' and 9- 5/8", 47# wire wrapped screen from 1,900' to 1,931'; Set packer at 1,803'. R/U to gravel pack well. Perform gravel pack,: placing 29,744 lbs of 12/20 sand behind wire- wrapped screen. R/D gravel packing equipmem. POH 10 stands. 12/24/00 PBTD: 2,478', Mud Wt.: 8.6 ppg POH w/3-1/2" tbg, gravel packing tools and wash pipe. Run 3-1/2" completion w/seal assembly, locator and x-nipple. Tag up on packer at 1'803' and space out. Circulate corrosion-inhibited brine and freeze protection diesel into tubing and annulus. Land tubing, run in lock-down screws, test packer and seals to 1500 psi - OK. Install BPV. Aurora Gas, LLC NCU#3 Workover 12/25/01 PBTD: 2,478', Mud Wt.: 8.6 ppg N/D BOP stack, N/U tree and test to 1500 psi- OK. Pull BPV, drain water from tree and replace w/diesel. Clean pits, release rig at 1800 hrs, 12/26/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 12/27/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 12/28/00 PBTD: 2,478', Mud Wt.: 8.6 ppg Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 12/29/00 PBTD: 2,478', Mud Wt.' 8.6 ppg Rig down, transport rig components to Tyonek Contractors' yard, stack rig. location. Clean 12/30/00 PBTD: 2,478', Mud Wt.' 8.6 ppg Demobilize crews. Release M/V Arctic Wolf. RECEIVED J/~N 3 1 2001 Alaska Oil & Gas Cons. Commission Anchorage ~e:-i~-_.~#3 Gas Test: Applicable Regs Subject: Re: NCU#3 Gas Test: Applicable Regs Date: Thu, 18 Jan 2001 09:26:21 -0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: Bill Penrose <bill@fairweather. com> BCC: Wendy D Mahan <wendy mahan@admin.state.ak, us>, ,J,0hn D Hartz <jack hart~7@admin.state.ak, us>, Camille O. Taylo¢"~Cammy_Taylor@admin.state.ak. us>, Dan Seamount <dan_seamount@admin.state.ak. us>, Tom Maunder <tom maunder@admin.state.ak, us>, Robert P Crandall <~ob crand~ll@admin.state.ak, us>, Stephen F Davies <stev~_davies@admin.state.ak. us> Morning Bill, I forwarded your questions to AOGCC staff. Please see the italized, underlined responses to your questions. Regards Julie Bill Penrose wrote: Dear Ms. Heusser, Following up on our telephone conversation, I'm requesting the Commission's review of our interpretation of the Regulations for a planned gas well test. Having worked over the Nicolai Creek Unit #3 gas well, Aurora Gas, LLC (the Operator) and Fairweather E&P Services, Inc. (the Operator's representative in Alaska) now plan to test it, using portable gas testing equipment, before placing the well on permanent production. We plan to test the well in late January/early February and it will involve venting the gas to the atmosphere during the test. While this well test is included in the approved Application for Sundry Approval for this well, we would like to ensure that we have a clear picture of our operational and reporting responsibilities as regards the Commission. Examination of the AOGCC Regulations indicates to us the following: 1. Per 20AAC25.235(d)(6), "upon application, the Commission will in its discretion, authorize flaring or venting of gas for purposes of testing a well before regular production." Question: What form does our request to the Commission need to take? The application is in the form cfa letter or part cfa 10.403. Since a 403 has already been Submitted and -a~'~)ved for this particular well, a letter requesting authorization to flare should be submitted. 2. It appears that, according to Section (b) of 25.235, the volume vented must be reported on Form 10-422, Facility Report of Produced Gas Disposition. Is this correct for this situation? The form ~0-422 is used to r_e~ort gas flaring associated with a facility. Since this is a one time WELL event (not facility), the 10-422 is not appropriate. The volume of gas flared should be reported on the 10-421, the Gas Well open Plow Potential Test Rep.ort. 3. Finally, since we will probably test this well using a 4-point backpressure test, it appears we should do so per 20AAC25.225, Potential of Gas Wells, and be prepared to submit Form 10-421, Gas Well Open Flow Potential Test Report. Is this correct for this situation? Yes. I would appreciate it if you would comment on our interpretation of these regulations and let me know if we've missed anything. Aisc, if the Commission has electronic versions of the forms mentioned above, I would appreciate receiving them. At this time, we have not approved the electronic version of these forms. In general, electronic forms are in the wori(s but not finalized yet. Thank you for your attention to this matter. I can be reached by phone at 258-3446 or by e-mail at bill@fairweather, com. Bill Penrose 1/21/01 7:17 PM urora Gas, LLC WWW. a urorapower, corn Janum3t 11,2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Nicolai Creek Unit No. 3 Permit to Drill 167-007 Sundry Notice 300-247 BOP Test, December 16, 2000 Dear Commissioner Heusser: Regarding response to your letter of December 26, 2000, concerning this matter, Aurora Gas, LLC, as operator of the Nicolai Creek Unit, has reviewed the response letter dated January 10, 2001, from Bob Gardner of Fairweather E & P Services, Aurora's representative on the rig for the workover of the No. 3 well, and agrees with its content. Sincerely, cc: Bob Gardner, Fairweather Bill Penrose, Fairweather 5718 Westheimer, Suite 1180 · Houston, Texas 77057 · (713) 977-5799 · Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220 ° Anchorage, Alaska 99501 · (907) 277-1003 · Fax (907) 277-1006 E & P SERVICES, INC. January 10, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7* Ave., Suite 100 Anchorage, Alaska 99501 RE: Nicolai Creek Unit #3 BOP Test, December 16, 2000 Dear Commissioner Heusser, We are in receipt of your letter of December 26, 2000 wherein you expressed your concern at our non-compliance with 20AAC25.033(c)(1) and (2) during the initial stages of the workover of the Nicolai Creek Unit #3 well. To re-cap, the AOGCC inspector witnessing a routine BOP test on December 16 noticed a lack of required pit monitors and fluid flow sensor on the rig. The rig was shut down until the necessary equipment was installed and calibrated on December 17. Fairweather, as the operator's representative, and Aurora Gas, LLC, as the Operator of record, admit the oversight. The lack of required equipment should have been noticed much earlier and the situation remedied prior to the commencement of downhole operations. A review of events prior to December 16 indicates clearly that the focus of the people involved was on operational difficulties being experienced at the surface and not sufficiently on the compliance of the equipment being used to monitor downhole conditions. To avoid future non-compliance occurrences, we have begun drafting a procedure for the systematic review of rig equipment, personnel training/qualifications and operational procedures with the focus being on regulatory compliance and safe operations. This review will be conducted prior to commencing any new project or activating a rig not used by us in the recent past. The following is our response to your request for additional information: 1. An operations chronology is attached. 2. The equipment installed on the rig to correct the oversight was: 1 ea DAQ (Digital Acquisition Unit) 1 ea VXC (Visuloger) 5 ea Pit Probes 1 ea Flow Sensor 1 ea Stroke Counter 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Ms. Julie Heusser 1 / 10/00 Page 2 1 ea Alarm 1 ea Keypad All sensors were calibrated and their proper operation verified upon installation. o The oversight had two causes. First, this equipment is such a standard part of most rig packages that the personnel "assumed" that the rig had all that was needed. Second, up to the point at which the oversight was discovered, the vast majority of operations were centered around solving problems at the wellhead and the downhole systems were just beginning to be utilized. . As discussed above, a procedure will be established for the systematic review of rig equipment, personnel training/qualifications and operational procedures with the focus being on regulatory compliance and safe operations. This review will be conducted prior to commencing any new project or activating a rig not used by us in the recent past. o An integral part of the established review procedure referenced in (4) above will be a verification that all appropriate planning and operations personnel are familiar with the pertinent AOGCC regulations. o The Operator's Representative, Toolpusher and Driller are certified at the Drilling, Workover and Completion Supervisor level in compliance with MMS 30 CFR 250 - Subpart O. The Operator's Representative is certified on surface and subsurface stacks. The Toolpusher and Driller are certified on surface stacks. We hope this sufficiently responds to your request for information and adequately addresses our proposed methods for avoiding similar occurrences in the future. If you have any questions or require additional information, please contact me at (907) 258- 3446. Sincerely, FAIRWEATHER E&P SERVICES, INC. Robert C. Gardner President enclosure Ms. Julie Heusser 1 / 10/00 Page 3 cc: Mr. Ed Jones- Aurora Gas Mr. Bill Penrose - Fairweather Event Chronology NCU #3 Workover 11/30/00 Living accommodations (M/V Arctic Wolf) arrived on beach at Shirleyville. Drilling crew arrived, underwent accommodation vessel orientation. Prepared rig components for moving out of Tyonek Contractors' yard to Nicolai Creek Unit #3 location. 12/1/00 Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/2/00 Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/3/00 Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/4/00 Transport rig components from Tyonek Contractors' yard to NCU #3. Rig up. 12/5/00 Transport rig components from Tyonek Contractors' yard to NCU #3. BPV. Rig up. Install 12/6/00 Finish rigging up. Rig accepted at 1400 hrs. N/U BOPs. 12/7/00 Finish N/U BOPs and flowline. Test BOPE. 12/8/00 Test accumulator. N/U and thaw trip tank. Pull BPV. Back out lock downs on tbg and unseat tbg hanger. Circulate well. 12/9/00 Circulate well. POH w/2-7/8" tbg. Change pipe rams to 3-1/2". P/U cleanout bit, DC's and 3-1/2" tbg and RIH. 12/10/00 RIH w/3-1/2" tbg to 2007'. Wash out fill f/2007' to 2053' 12/11/00 Wash fill to 2462' while circulating and sweeping hole. 12/12/00 (Waiting on packer) Circulate well. POH. Repair hydraulic leak. M/U 7" casing scraper, RIH, pump sweep around. 12/13/00 Circulate well while waiting on packer. 12/14/00 Circulate well while waiting on packer. plug. WOC. Informed packer will not make it. Set cement 12/15/00 Test cmt plug. N/D BOP stack. N/D tbg spool. N/U and test new tbg spool. 12/16/00 N/U BOP stack. Test same. Rig operations shut down when AOGCC inspector noticed lack of pit level and flow show indicators (PVT system). 12/17/00 Wait on PVT system. Install and calibrate PVT system. 12/18/00 P/U bit and 7" csg scraper. Drill up cement plug. RIH, adding 13-3/8" scraper to string. Circulate and condition well. 12/19/00 Circulate viscous sweep. same. Circulate caustic sweep. Displace well to KC1 brine and filter 12/20/00 POH. R/U wireline, run GR/CCL correlation log. P/U 4" perforating guns and perforate 7" liner 2360'-2380', 2308'-2328'. 12/21/00 Perforate 7" liner 2302'-2308', 2218'-2238', 2201'-2218', 2012'-2032', 2005'-2012'. R/D wireline. M/U 7" perforating guns on 3-1/2" tubing and RIH. Space out and perforate 13-3/8" casing 1900',1930'. POH and L/D guns. RIH w/7" and 13-3/8" csg scrapers. Circulate well, pump hi-vis sweep. 12/22/00 Circulate and filter brine. POH and L/D scrapers. R/U wireline, set bridge plug in 7" liner below perfs, R/D wireline. Prepare to run wire-wrapped screen. 12/23/00 RIH w/wire-wrapped screen and wash pipe, set across perforated intervals in 7" and 13- 3/8" casing. Set packer. R/U to gravel pack well. Perform gravel pack, placing 30,000 lbs of sand behind wire-wrapped screen. R/D gravel packing equipment. POH 10 stands. 2/24/00 POH w/3-1/2" tbg, gravel packing tools and wash pipe. Run 3-1/2" completion w/seal assembly, locator and x-nipple. Tag up and space out. Circulate corrosion-inhibited brine and freeze protection diesel into tubing and annulus. Land tubing, test packer and seals to 1500 psi - OK. Install BPV. 2/25/OO N/D BOP stack, N/U tree and test to 1500 psi - OK. Pull BPV, drain water from tree and replace w/diesel. Clean pits, release fig. 2/26/00 Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 2/27/00 Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 2/28/00 Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 2/29/00 Rig down, transport rig components to Tyonek Contractors' yard, stack rig. 2/30/00 Demobilize crews. ALASI~A OIL AND GAS CONSERVATION COPIPlISSION I TONY KNOWLES, (~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 26, 2000 Mr. J. Edward Jones Vice President Aurora Gas, LLC 5718 Wcsthcimer, Suite 1850 Houston, TX 77057 Mr. Bob Gardner President Fairweather E & P Services 7 ! 5 L Street Anchorage, AK 99501 in Re: Nicolai Creek Unit #3 Permit to Drill 167-007 Sund~ Notice 300-247 BOP Test, December 16, 2000 Dear Mr. Jones and Mr. Penrose: During the course of a routine BOP test and general rig inspection on your well Nicolai Creek Unit # 3, the Commission became aware of a potentially serious event. Our concern is twofold: (1) the necessary pit monitoring equipment was not present on thc rig as required by AOGCC regulations; and (2) the absence of this pit monitoring equipment appeared to go unnoticed by drilling personnel. To help us understand the actual event chronology and develop a way forward, we are in need of additional information. As you are aware, the drilling fluid and drilling fluid processing and monitoring system employed on a well is considered the primary means of maintaining well control. During the December 16 inspection of Nicolai Creek Unit #3, it appears that AOGCC regulations 20AAC25.033(c) (1) and (3) were not satisfied. Thc requirements for fluid flow and level monitoring equipment are found at 20 AAC 25.033 and in particular are as follows: 25.033 (c) A drilling fluid system intended to maintain the wellbore in overbalanced condition must include ( ! ) a recording drilling fluid pit level indicator with both visual and audible warning devices located in the immediate are of the driller's satin: (2) a drilling fluid measuring system or trip tank for accurately determining drilling fluid volumes required to fill the welibore on trips; (3) a drilling fluid flow sensor with a-readout convenient to the drillers station to enable thc operator to determine whether drilling fluid returns equal drilling fluid pump discharge rates; equipment to keep the drilling mud conditioned as appropriate for the drilling operation being conducted; and methane and hydrogen sulfide detection equipment as required by 20 AAC.25.066 (4) (5) J. Edward Jones 2 Bill Penrose December 26, 2000 We look forward to receiving the needed additional information. In particular, we ask you to provide the following: (1) An operations chronology prior to and following the December 16 AOGCC inspection. (2) A description of the equipment that was installed on the rig to correct the equipment oversight. (3) A more complete understanding of how the equipment oversight occurred. (4) A detailed description of your future plans to insure all required equipment is present on a rig prior to its acceptance as fit for operation. (5) A detailed description of-your future plans to insure all appropriate personnel have a solid working understanding of AOGCC regulations. (6) The current well control training status of all Company Representatives, Tool Pushers and Drillers who were involved in rig operations associated with Nicolai Creek Unit #3 prior to the December 16, 2000 inspection. Thank you for your prompt attention to this request. We look forward to receiving your response by January 16, 2001. Should you have any questions, please feel free to contact either Tom Maunder (793- 1250) or myself (793,1221). CC: Bill Penrose, Sr. Project Mgr., Fairweather E & P Very truly yours, Julie Heusser Commissioner ~EC--18--,80 10= 1~ AM INLET ~RLG RK 19072559640 RUSH ~ YES INLET DRLG RK 19072659640 CUSTOMER ~(~/Z~/'~,.~ ~',~..~,,' LEASE OR RIG PHONE: ~¢~'~'.- ~'~;D.r.)~',./_ DATE RECFIVED ~ECEIVt~D BY DATE REQUIRED TYPE OF INST. SEI~IAL NO, AND/OR SET PRESSURE P.02 REPAIR ORDER No.084544 /? DATE R£PAIR$ COMPLI=TL""D REMARKS pARTS USED IN REPAIRS QUANTITY PART NUMBER DESCRIPTION . ,,,,. .......... ' ' , ,,. ...... · --- ~ , , . .. ,,,,,. ,,, ,,, .,,, ,,, ,,,,, ,,,, a ...... ~.,~_ .,, ., . _., ............ ,, ,, ,, , . ..., . ,,,,, ,,, , . , ..- ~ .. ... , ,,,,,,. ,,,,. .... . J .... ~ . . .... ,.., ~tPAIR X ~--AUTHO~IZED BY INVOIC~ NO. -' ._ ~... , ....... ., ,,, ...... BEC-- ! ~--~] 8TATE OF AI.A~KA OiL AND ~ (~ONIEI~ATION Tilt ........... _~.~ ..... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: December 16, 2000 SUBJECT: Blowout Preventer Test Inlet Drilling CC1 Aurora Gas / NC #3 Nicolai CK Unit #3 167-007 NCF / NCU NON- CONFIDENTIAL Operator Rep.: Bill Penrose Contractor Rep.' Joe Steiner Op. phone: 244-5704 Op. E-Mail: Rig phone: Rig E-Mail: Test Pressures Rams: 250/2000 MISC. INSPECTIONS: P/F Location Gen.: P Sign: Housekeeping: P Rig cond: PTD On Location P Hazard: Standing Order: P BOP STACK: Annular: 250/2000 Choke: 250/2000 TEST DATA FLOOR VALVES: MUD SYSTEM: P/F Quantity P/F Trip Tank P Upper Kelly 1 P Pit Level Indicators P Lower Kelly 1 P Flow Indicator P Ball Type 1 P Meth Gas Detector Inside BOP 1 P H2S Gas Detector Visual Alarm P F F F F F P P P P Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5~8" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 3.5" P Quantity P/F System Pressure 3000 P Lower Pipe Rams N/A No. Valves 11 P After Closure 1350 P Blind Rams 1 13 5~8" P Man. Chokes 1 P 200 psi Attained :32 P Choke Ln. Valves 1 4" P Hyd. Chokes 1 P Full Pressure 3:10 P HCR Valves 1 4" P Blind Covers (All Stations): P Kill Line Valves 2 2" P N2 Bottles (avg): 4~2100 P Check Valve N/A Test's Details Saturday, December 16, 2000: I traveled to the Aurora Gas Nicolai Creek Unit well #3 to witness a weekly BOPE test on Inlet Drlg. Rig CC-1. The Inlet Drlg. crew was rigging up to test BOPE on my arrival, and I conducted a rig inspection and witnessed a successful test of the gas detection alarm system in the interim. The rig and it's equipment appeared in good condition and the location was organized. I noted the absence of a drilling fluid alarm system as required by Alaska State regulations, and discussed this concern with Bill Penrose (Aurora Gas Rep.) and Joe Steiner ( Inlet Drlg. Rep.). Mr. Penrose immediately began efforts to secure the necessary equipment for installation on the rig. After discussing the situation with Tom Maunder ( acting AOGCC Inspections Grp. Supervisor), Chuck Seheve and Lou Grimaldi (AOGCC Inspectors), it was decided that the operator would shut in the well and cease wellbore operations until the required mud pit volume and flow indication alarm system is installed and tested. Otherwise, the testing proceeded smoothly, with no other failures. Summaw: I traveled to Aurora Gas well NCU #3 and witnessed a weekly BOPE test on Inlet Drlg. Rig CC-1. The required Primary Well Control equipment (drilling fluid alarm system) was not installed and the operator (Aurora Gas) was instructed to shut the well in and discontinue well bore operations. Total Test Time: 4.5 hrs. Number of failures: _5 Attachments: 0 cc: BOP Test (for inspectors) BFL 11/20/00 BOP Inlet Drlg CC-1 12-16-00 JJ.xls September 22, 2000 Mr. Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Application for Sundry Approval: Nieolai Creek Unit #3 Dear Commissioner Christenson, Aurora Gas, LLC, through its local operations consultant Fairweather E&P Services, Inc., hereby applies for Sundry Approval to work over Nicolai Creek Unit #3 to return the well to gas production. The well will be cleaned out, re-perforated and a gravel packed screen installed. The well will then be completed as a gas producer and tested. After installation of a pipeline, the well will be produced to the Granite Point Facility. Please find attached the following information for your review: 1) Form 10-403 Application for Sundry Approval 2) Proposed procedure for working over the well 3) Well schematic showing the present condition of the well 4) 3,000 psi WP wellhead schematic 5) 13-5/8", 5,000 psi WP BOP schematic 6) 3", 5,000 psi WP choke manifold schematic If you have any questions or require additional information, please contact me at (907) 258-3446. Sincerely, FAIR~~ E&P SERVICES, INC. Bill Penrose Sr. Project Manager REC;EIVED enclosures cc: Mr. Ed Jones - Aurora Gas, LLC SEP 22 2000 Alaska & Gas Cons. Commi ion Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 /? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] S~spend [ ] Plugging [ ] Ti~e Extension IX] Perforate [ ] Alter Casing [ ] Repair Well [X] Pull Tubing [ ] Variance [ ] Other [ ] Change Approved Program [ ] Operation Shutdown [X] Re- Enter S,uspended Well ~ Stimulate 2. Name of Operator ' ' 5. Type of well: 6. Datum Eleva{i(~n (DF or KBi Aurora Gas, LLC [X] Development -216' (K.B.) [ ] Exploratory 3. Address [ ] Stratigraphic 7. Unit or Property Name 5718 Westheimer, Ste 1850, Houston, TX 77057 [ ] Service Nicolai Creek Unit '4. LOcation Of well at surface 8. Well Number i668' FWL, 3369' FSL, Sec. 20, T11N, R12W, SM 3 At top of productive interval 9. Permit Number (@ 1900' MD) 1662' FWL, 3366' FSL, Sec. 20, T11N, R12W, SM 167-00,7 At effective depth 10. APl Number (@ 2478' MD) 1660' FWL, 3363' FSL, Sec, 20, T11N, R12W, SM 50-283-20003 At total depth 11. Field and Pool (~ 8841' MD) 1290' FWL, 3035' .FSL, Sec. 20, Tl1. N, R12W, SM Nicolai Creek '"12. Present well condition summary ........ Total depth: measured 8841' feet Plugs (measured) 6890' - 7000, 50 sx cement true vertical 8841' feet 4915' - 5000, 50 sx cement Effective depth: measured 2478' feet 2478' - 2656, 100 sx cement true vertical 2478' feet Junk (measured) Casing Length Size Cemented M D TVD Structural Conductor 264' 20" 720 sx 282' 282' Surface 1985' 13-3/8" 1770 sx 2001' 2001' Intermediate Production Liner 581' 7" 220 sx 1941' - 1941' - 2522' 2522' Perforation depth: measured 1900-30', 2005-20', 2201- 38', 2302-28', 2360 - 81~ ~... ~,,~ i-., iHi~ r,~ 2 aa, 1/2" holes per foot, all open True vertical Same Tubing (size, grade and measured depth) 2-7/8", 6.5~, N-80 at 1908' SEP 2:2 2000 Packers and SSSV (type and measured depth) NoneORIGINAL Alaska 0~ & Gas Cons. Commission Anch0mge 13. Attachments [ ] Description of Sumary Proposal [X] Detailed Operations Program [x] BOP Sketch '" 14. Estima{ed date for commencing operation 15. Status of well classification as: ........................... October 15, 2000 16. if proposal was verbally approved [ ] Oil [ ] Gas ~] Suspended Name of approver Date Approved Service Contact Engineer Name/Number: Bill Penrose g07-258-3446 Prepared By Name/Number: Bill Penrose g07-258-3446 i7. I hereby ce,ti,fY that th..h..e~regoing is t,me'~nd correCt tO the best of my knowledge Signed ~.~~~,__~~,,f'"/,-jT J. Edward Jones itle Vice President Date // ..... -- '~onditions qf,~:)proval: Notify Co)~,,~ssion so rePresentative may witness ' IApproval No. I~e,~Z~i, ,~"~ ~t~ug inte~ty BOP Test ,,i Location Clearance /~3 Pt.(~f4$ ~ ~,406c.¢ Mechanical Integrity Test_~ Subsequent form required 10- Al~t~'a{'~c,r,~F "f"o u.~..- O_RtGiNAL SIGNED BY , ,. Approved by order of the Commission [3 3'avl,-,,- e ......... Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Td[ ate AURORA GAS, LLC NICOLAI CREEK UNIT NO. 3 APPLICATiON FOR SUNDRY APPRO VAL-PROPOSED PROCEDURE TO RETURN TO PRODUCTION 1. Clear and restore location. 2. Move in drillingJworkover rig w/subbase and rig up. Move in mud pump and tanks: (1) 400-bbl for displaced mud, (1) 400-bbl for water, (1) open 100-bbl steel mud pit w/gas buster. 3. Ensure well is dead. Set BP valve in tubing hanger. Nipple down tree. NU 13-5/8", 5000-psi BOP stack. Test to 250/1500 psi. Pull BP valve. 4. Circulate and condition mud in hole (if well was not dead during R/U, do this before ND tree above). Pull 2-7/8" tubing, lay down and visually inspect (1,908'). 5. Pick up 3-1/2" robing w/6" bit and drill collars. Run in hole and clean out 7" liner to +/- 2,478'. . Mix 400 bbl treated water (3% KC1 w/additives). Displace mud from hole. Circulate and filter completion fluid to acceptable NTU level. POH w/ tubing, keeping hole full. . RU lubricator and wireline. Re-perforate present intervals (1,900-1,930', 2,005-2,020', 2,201-2,238', 2,302-2,328' and 2,360-2,380') and add 2,020- 2,032' w/Schlumberger 4-1/2" guns w/12 SPF in 7" liner and 7" gun w/ 18 SPF in 13-3/8" casing. POH w/guns. . Pick up Baker Gravel Pack Assembly (500' 3-1/2" SS wire-wrapped screen w/bull-nose shoe, 9-5/8" X 3-1/2" X-O, 30' 9-5/8" Bakerweld 140 Screen, 60' 5-1/2" Blank Tubing, 5-1/2" Shear-out Safety Joint, 5-1/2" Model C KOIV, 5-1/2 X 7" crossover, Sliding Sleeve w/Lower SB Extension, Upper Extension w/SB, 13-3/8" DB Packer) on tubing w/500' 2-3/8" flush joint tail pipe and crossover tool. Run assembly in hole with packer at 1830'. RECEIVED SEP 22 2000 Alaska 0~ & Gas Cons. Commission Anchorage 9. Gravel pack screen in place w/+/- 250 sx 12/20 sand at ~A-1 ppg in KC1 water at 8-10 bpm. 10. Circulate packer fluid (KC1 water w/corrosion inhibitor). Set and test packer. POH. 11. Pick up and run seals and locator on 3-1/2" robing. Stab into packer and test seals to 1000 psi. Land tubing. 12. ND BOP stack and NU tree. Rig up test separator and lines. 13. Swab well in, flow to separator. 14. When well is flowing satisfactorily, rig down rig and other equipment. 15. Proceed w/well cleanup and testing. Ed Jones (9/21/00) 282' 9 ppg Mud in 13 3/8" Casing and 7" Liner ~ 26" Hole Size 20', 8.5#, Cemented w/720 sx 2 7/8", 6.5#, N-80 Open Ended, Tubing to 1,908' 17 1/2" Hole Size 1 ,g41' 2 SPF, 1,900' - 1,930' 7" Liner Top 2,001' Fill @ 4- 2,200' 9 7/8" Hole to TD PBTD @ 2,4.78' 2,522' 13 3/8", 54..5#, Cemented w/1,770 sx 2 spf, 2,005' - 2,020' 2 spf, 2,201'. - 2,238' 2 spf, 2,502' - 2,528' 2 spf, 2,360' - 2,380' 7" Liner, 29#, N-80, Cemented w/220 sx 50 sx Cement Plug from ~ 4.,915' to 5,000' 50 sx Cement Plug from ~ 6,890' to 7,000' TD @ 8,84-1' NO SCALE FAIR/AURORA/NCUWELL 1:1 5/26/00 SR Aurora Gas LLC Nicolai Creek Unit No. 5 Well Schematic LEGEND Cement Fill RECEIVED SEP 22 2000 Alaska 0~I & Gas Cons. Commission Anchorage 3000# Tubing Head 7 1~16", 3000# Tree (;ap ~ w/5 NPT 2 1/2" x 7 1/16", 5000# Tree Block w/Internal Wing Valve 20" x 13 5/8" Casing Spool 20" BradenheadL~ 2" x 1 5/16", 5000~ 2" x 2 1/16", 5000~ 2" x 2 1/1e", 5000# NO SCALE FAIR/AURORA/NCU 1:1 5/26/00 SR Aurora Gas LLC Nicolai Creek Unit No. Wellhead Schematic RECEIVED SEP 22 2000 Alaska 0~ & Gas Cons. Commission Anchorage 2-1/16" :MANUAL KILL 2-1/16" : .. . I BLIND RAMS, 5M" ~~ 4'1/16' I SEC: SEC (~ NOTE: All choke anti kill valves are rated at 5M WP 4-1/16" HYDRAULIC CHOKE LINE RIG SUBBASE GROUND LEVEL AURORA GAS, LLC NICOLAI CREEK UNIT 13-5/8', 5M BOP SCHEMATIC RECEIVED SEP 22. ~000 Alaska 0~; & Gas Cons. Commission Anchorage , HYDRAULIC CHOKE MANUAL CHOKE 4 -WAY CROSS NOTE: ALL VALVES ARE 3", 5M PSI WP TO PITS POOR BOY DEGASSER CHOKE HOUSE WALLS 4-WAY CROSS AURORA'GAS, LLC NICOLAI CREEK UNIT 3", 5M PSI CHOKE MANIFOLD RECEIVED SEP 22 2000 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 Kevin Tablet, Land Manager UNOCAL P O Box 196247 Anchorage, AK 99519-6247 ~ ( Re: Suspended Wells Compliance with regulations Dear Mr. Tabler: UNOCAL has 15 suspended wells as shown on the attached list: SUSPENDED WELLS AS OF AUGUST 1994. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached list of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells'that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections as appropriate this year prior to snow covering the locations. · Chairman c: Blair Wondzell enci bew/llunsusp A~'ASF~% SUSPEDRD ~LLS AS OF AUGUST 1994 PERMIT API NUMBER OPERATOR W~LL NAM~ WELL WELL STATUS CLASS STATUS DATE SECT TWP RNG MER 00-0146-0 133-10145-01 UNION OIL CO 61-0045-0 133-10144-01 UNION OIL CO 66-0008-0 283-10020-01 U~ION OIL 66-0038-0 283-10021-00 U~ION OIL 283-20003-00 U~ION OIL 67-0023-0 733-20018-00 U~ION OIL CO 67-0042-0 733-20032-00 UNION OIL 72-0007-0 133-20237-00 U~ION OIL 75-0008'-0 283-20045-00 U~ION OIL 77-0017-0 733-20300-00 U~ION OIL CO 78-0096-0 733-20119-00 U~ION OIL 79-0017-0 733-20441-01 UNION OIL 81-0022-0 733-20339-00 U~ION OIL 90-0041-0 733-20302-01 UNION OIL CO 90-0071-0 733-20417-00 UNION OIL CO SWANSON RIV UNIT 14-15 SWANSON RIVUNIT 43-15RD NICOLAI CK ST 1-A NI~OLAI C.K UI~IT 2 N~i~ CK UNIT ~!~!, G~ITE PT ST 18742 9 GP~ITE PT ST 18742 10 SWA/~SON RIVUNIT 24-33 i'VA~ RIVER U~IT 14-31 MGS ST 17595 16 G~%NITE PT ST 18742 31 GRANITE PT ST 18742 34 GI~m~NITE PT ST 18742 40 TP~tDIN~ BAY ST A-20P. D T~DING BAY LT~IT M-04 DEV SUSP 11/08/91 16 08N 009W S DEV SUSP 8/20/91 15 0SN 009W S DEV SUSP 8/14/91 29 11N 012W S D~V SUSP 9/18/91 29 11N 012W S D~V SUSP 9/02/91 20 11N 012W S D~V SUSP 9/16/89 12 10N 012W S SER SUSP 9/29/88 31 11N 011W S DEV SUSP 4/01/93 04 07N 009W S DEV SUSP 8/18/75 01 13N 009W S D~V SUSP 2/05/92 31 09N 012W S SER SUSP 10/07/88 31 11N 011W S D~V SUSP 9/20/91 31 11N 011W S DEV SUSP 4/21/82 31 11N 011W S D~V SUSP 4/23/90 04 09N 013W S D~V SUSP 7/03/90 33 09N 013W S Unocal North America; Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region September 24, 1991 Mr. Lonnie Smith AOGCC 3001 Porcupine Drive Anchorage, AK 99504 Dear Lonnie: Unocal elected not to perform workover operations on Nicolai Creek State #3. There are no detectable gas leaks around the well. On September 20, 1991 the well was killed with 81 PCF drilling mud and left in a suspended condition. Since this well is not on the airstrip we feel that the well is in a safe condition. The following 10-404 form is to close out form 10-403, approval ~91-81. Sincerely, ~_~~..~. Z:. ~~~. George R. Buck Drilling Engineer GRB/lew RE¢'EIVED SEp ~ 0 199! Alaska OiJ & Gas Cons. 1. Operations performed: Operation shutdown Pull tubing __ A ter casing 2. Name of Operat~rUNOCAT, ) ] 5. Type of Well: · ' ' nia Development .2~ Union Oll Company of Cal~for .... . ~-xplora[ory ~./~aaress P.O. Box 190247, Anch., AK, 99519 I Se~ice~ 4. Location of well at surface l b b ~'~ ~ ~ 33b~' N f'rom ~.W. ~orner Sec 20, TllN, R12W,. SM AttopofDroductiveinterv~900'), 1662' E, 3366' N from S. W. corner, Sec. 20, (2517'), 1660' E, 3~cti~d~Prthom S. W. corner, Sec. 20, (8841'~, 1290' E, 30~t~ald~thfrom S. W. corner, Sec. 20, .;'~,, STATE OF ALASKA AL/-. A oILAND GAS CONSERVATION COMMI~ )N' REPORT-OF SUNDRY WELL OPERATIONS Other TllN, R12W SM TllN, R12W SM TllN, R12W, SM 6. Datumelevation(DForKB) + 216' KB ZUnitorPropedyname Nicolai Creek feet Uni 8. Well nq_rr~er., N~co±ai Creek #3 9. Permit number/approval number 10. APl nu~nber 5o-01 3- 0003 -00 11. Field/Pool Nicolai Creek 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5,011' 5,010, f~t Plugs(measured) ~et 3,540' ~ Junk(measured) 3,540' feet Cement plug 7221'-7318' Cement plug 2517'-5656' None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: .~ngth 264' 1985' 581' measured Size 20" 13-3/8" 7" Cemented Measureddepth ~ueverticaldepth 720 sacks 282' 282' 1770 sacks 2001' 2001' 220 sacks 1941'-2522' 1941'-2522' true vertical See attachment Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-7/8" , 13. Stimulation or cement squeeze summary' Intervals treated (measured) None (The Work Treatment description including volumes used and final pressure 6.4#, None N-80 at EE"EEIVED REP 5 0 Alaska Oil & Gas Gons. ~1~11 was not done) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation None Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations __ Oil __ Gas __ Suspended .X. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Regional Drilling Manager Gary ~ Bush Signed ~. c~-~~. (~ ,.,-o~ Title Form 10-404 Rev 06/15 8/~ ~ Datec) - 2 q, -~ \ SUBMIT IN DUPLICATE ATTACHMENT A UNOCAL TOP MD TVD 1900 1900 2005 2005 2201 2201 2302 2302 2360 2360 BOTTOM 1930 2020 2238 2328 2380 TVD 1930 2020 2238 2328 2380 INTERVAL 30 15 37 26 20 CONDITION OPEN OPEN OPEN OPEN OPEN Unocal North Americ/''~', Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region June 21, 1991 Alaska O&G Conservation Commission Attn: Lonnie C. Smith 3001 Porcupine Drive. Anchorage, AK 99504 Dear Mr. Smith: Unocal is proposing to suspend the three Nicolai Creek wells: #l-A, #2 and #3. Presently, the calculated quantities of gas and low reservoir pressure make completing these wells uneconomic. Unocal however has future plans to install compression facilities in the Granite Point area. It is'anticipated that offshore gas reserves will be developed and compression facilities installed sometime in the mid-1990's. Once compression facilities are installed we will again be able to evaluate the economics of completing the Nicolai wells. Unocal does not wish to accept the economic and environmental risk associated with leaving the three wells in their present condition until gas compression facilities are available. All three wells are presently completed without packers and have gas under pressure at the surface. The Nicolai #1-A and #2 wells are at the end of the Nicolai Creek Airstrip and gas is leaking from the annulus between the 20" and 13-3/8" casing in the Nicolai #i-A well. For these reasons Unocal is proposing to suspend the three wells thereby removing pressure from the surface. On July 15, 1988 UNOCAL and Marathon Oil Company purchased the Nicolai Creek Unit from Texaco, Inc. and Mobil Oil Company. The working interest in the Nicolai Creek Unit is 50% UNOCAL and 50% Marathon Oil Company. All of the wells were originally drilled by Texaco, Inc. from 1965 to 1979. The following is a short history of the wells we are proposing to work on. R£' 'liVED JUL 10 1991 Alaska Oil & Gas,Cons. Comn'~ssion AOGCC JUNE 21, 1991 PAGE 2 Texaco, Inc. commenced drilling operations on Nicolai Creek State #1 on October 31, 1965. On November 23, just after the 13 3/8" casing was cemented, gas began blowing to the surface for 4-5 hours. The gas flow slowed to a slow leak, was seen coming out of the ground at several points around location and out of the nearby water well. Several cement squeezes were performed and the gas flow slowed. The well was drilled to a depth of 9302' by April 9, 1966 and the 7" casing was run to surface. The Hemlock oil sands from 6685' to 7850' were tested and showed no oil accumulations. The Hemlock sands were abandoned with cement and the 7" casing was pulled from 3780'. The Tyonek gas sands between 3420' and 3630' were perforated, tested and completed. The well work was completed on May 2, 1966. Nicolai Creek #1-A was produced for a total of three months from December 1968 through February 1969, the well was shut in during March 1969 when the well sanded in. The well has been idle since March, 1969. The average peak rate was 1.8 MMCFD and produced a total of 117 MMCF. As unit operator UNOCAL is proposing to suspend the well in the manner indicated by the attached schematic. Texaco, Inc. commenced drilling operations on Nicolai Creek State #2 on September 21, 1966. After cementing the 20" casing into place on September 30 a small gas flow was observed between the 20" casing and the 30" casing. This well is 20' away from the Nicolai Creek #i-A well, and it is believed that the gas was from that well. The well was drilled to 5011' and 7" casing was run to 3585'. No oil accumulations were encountered. The gas sand between 3270' and 3315' was perforated and tested on October 23, 1966. Drilling operations were completed on October 29, 1966. Nicolai Creek #2 was produced from October 1968 through November 1969. The well was shut in during December 1969 and has been idle since then. The average peak rate was 1.0 MMCFD and produced a total of 51 MMCF. As unit operator UNOCAL is proposing to suspend the well in the manner indicated by the attached schematic. gE £1V£D ,JUL 11 199t Alaska Oil & Gas COns. Commission Anchorage AOGCC JUNE 21, 1991 PAGE 3 Texaco, Inc. commenced drilling operations on Nicolai Creek State #3 on March 19, 1967. The well was drilled to a total depth of 8841' in an attempt to locate a Hemlock oil accumulation. No significant reservoirs were encountered. The well was plugged back to 2522' and a 7" liner was run and cemented from 1941' to 2522'. On May 2, 1967 the gas sands between 2000' and 2380' were perforated and tested. Drilling operations were completed on May 5, 1967. Nicolai Creek #3 was produced from March 1969 through August 1977. The well produced a total of 893 MMCF of gas and was shut in during September 1977. The average peak rate was 1.8 MMCFD. As unit operator UNOCAL is proposing to suspend the well in the manner indicated by the attached schematic. Sincerely, George R. Buck Drilling Engineer Attachment GRB/lew CURRENT PROPOSED NICOLAI CREEK.# 1-A NICOLAI CREEK # 1-A KB ,= 16' GAS LF..N,(ING ?O SURFACE SPUD 10-31-65 KB '"' 16' 44~ H-4o . 20 DEG U&X DI:V~TIOH lO :~/4'*, 4(usj · ~ 17' L ' i lQ ~X TQP ~ FWOU Si' B~B4 TI~ 2~ )~D TH~ 13 3/8' 400' ~ W/4O0 SX tOW ~ ~~ 1140' qU~TlOW~£ PE34L~l~T1QI4 GFrB ~/10/01 13 3/0" · 1904' 40~ a-SS 102P~ MUll MI~' - 3&10' 7' I:UI' AHD IqJU.EI] AT 3710' · ~-~~w/~ i7~ G W/~ ~ 1M0' BQZ'D ·/210 SX KB --, 15' NICOLAI CREEK CURRENT #2 ~" I-1~3LE 30"I BO' SPUD 9-21-66 26= H~LE 2O" · ~ cut,o w/~o sx 17 1/2= HOLE ANNLLU5 HAS IHHIBITED FRIDSH WATER 12 1/4= HOLE TO 2.12,2' 9 7/8' HOLE TO TO 2 1/:2 ~ FROM 3313 -- 3270' I 2 7/8% L,q~ TUBIHO TO 10 m ~011' : ' : I'VO - 4oee .. ................... cra 5/12/91 KB '-" 15' NICOLA! CREEK PROPOSED #2 SPUD 9-21-66 2I" HOLE 20" e 2If ,~ ~ W/6~0 sx 17 1/2'" HeLE claro w/1loo ax 15 1/4= HCLE TQ 2322' I ?/t' HQ.E TO 10 L Cl]~ENT ABANDI PLUg I~ROU 170' TO ~ILI~AC~ · · · · : : : : : : FROU 3~4~ - 3100' 1/2 ~ FROM 331~' - 3270' GRB 5/12/91 NICOLAI #3 NICOLAI KB = 16' SPUD MARCH 19, 1967 I(B = 16° 17 ~/2" HOLE MAX INCr. 11 OEO ~:5 ~/r, ~4.sj, · 2ool. CUT"D WI~ 1770 SX CREEK CURREN1' C~dE~'T PLUG F/ 2517' -- 56~4' CliENT PLUG F/7221' - 731~ cumw/72osx 2 ~ 2005' - 2020' 2201' - 223e' 2:502" - 2329" 2 SPF 2360' - 2380' 17 1/2- HC~ CREEK #3 PROPOSED SPUD MAECH 19, 1967 CEMENT Pt. UO PROM aO0" ~ ~ACE 2 ~ 200S* - 2020' · 7/o- 2 SPF 230Z - 2328' FlUe F/2.117 STATE OF AEASKA ALASKA OIL AND i3AS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend x Alter casing __ Repair well __ Change approved program __ Pull tubing _,3L Variance ~ 2. Name of Operator ( UNOCAL ) ! 5. Type of Well: Development ~ TT,-,-~----, ,'~ '~ r,,,,,,.,,,=,-.,, of C=_!iforni~- I Exploratory__ 3.-,~,~l"a r-e's's ....... =--" ! Stratig raphic __ p. o. Box ] 90 2 4.7: Anch.. AIl: 995 ] 9J Service __ 4. Location of well at surface 1668' E & 3369' N from S.W. Corner Sec 20, Ti iN, Ri2W, SM At top of productive intervall900 ' 1662 ' E 3366' N from S.W. corner Sec. 20, TllN, R12W SM At effective depth 2517' 1660' E , , 3363' N from S.W corner Sec. 20, TllN, R12W SM At total depth 8841', 1290' E, 3035' N from S.W. corner, Sec. 20, TllN, R12W SM Operation shutdown __ Re-enter suspended well _2[. Plugging _,~ Time extension ~ Stimulate _x_ Perforate ~ Other 6. Datum elevation (DF or KB) feet +71 R ' 7. Unit or F~P-e~ty name l~l-lco'lai Creek Onit 8. Well number Nicolai Creek St. #3 9. Permit number 7-oo7 10. APl number 0- q83- ,0 3-oo 11. Field/Poo~lioola~ Creek 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Length Structural Conductor 264 ' Sudace 1985 ' 5,011 5,010 3,540 3,540 Size feet Plugs(measured) Cement plug 7221'-7318' feet Cement plug 2517'-5656' feet Junk (measured) feet Cemented None Measured depth 20" 720 sacks 282' 13-3/8" 1770 sacks 2001' True vertical depth 282' 2001' 1941'-2522' ,, SUBMIT IN TRIPLICATE Intermediate Production Liner 581' 7" 220 sacks 1941'-2522' Perforation depth: measured See attachment A true vertical 2-7/8", 6.4#, N-80 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal __ at 1908' Detailed operations program 14. Estimated date for commencing operation J July 15, 1991 16. If proposal was verbally approved Oil __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed GARY S. BUSH r.,w~ Title REGIONAL DRILLING FOR COMMISSION USE ONLY 15. Status of well classification as: Conditions of approval: Nptily Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical In{e~3rity Test __ Subsequent form required 10- Gas __ Suspended MANAGERDate jApprovalNo, gJ-I '/ LONNIE C. SMITH Apl)roved Ool)Y ,Retu%ned Approved by order of the Commission _, j ,0. _,~._. !c::;j !. J Form 10-403 Rev 06/15/88 Commissioner ATTACHMENT A UNOCAL TOP MD TVD 1900 1900 2005 2005 2201 2201 2302 2302 2360 2360 BOTTOM MD 1930 2020 2238 2328 2380 TVD 1930 2020 2238 2328 2380 INTERVAL 30 15 37 26 20 CONDITION OPEN OPEN OPEN OPEN OPEN RECEIVED ~UN 1 '81991 NICOLAI CREEK #3 · · MOVE IN AND RIG UP. KILL WELL WITH 80 PCF MUD. 3. INSTALL AND TEST BOPE TO 3000 PSI. 4. POOH WITH THE TUBING. 5. CLEAN OUT TO ETD. 6. LAY A BALANCED CEMENT PLUG FROM ETD TO 2100'. 7. LAY A BALANCED CEMENT PLUG FROM 2100' TO 1700'. 8. WOC AND TAG THE TOP OF CEMENT. 9. LAY BALANCED CEMENT PLUG FROM 800' TO 400'. 10. LAY A BALANCED CEMENT PLUG FROM 400' TO SURFACE. 11. THE WELL HEAD IS NOT TO BE REMOVED. 12. RIG DOWN AND MOVE OUT. KB = 16' NICOLAI CREEK #5 CURRENT SPUD MARCH 19, 1967 26" HOLE 20' B5~ · 2e2' CU~D W/ 720 SX 17 1/2- HOL~ UAX INQ. 11 DEO 13 3/f'. ~4_~. · 2001. ~ WffH 1770 SX ~ l°t.U; Fl 7221' - 731~ 2 51=F 2005' - 2020' 2 .Pt= 2201' - 2238' 2 ~ 2302' - 2328' 2 ~ 2360' - 2380' KB = 16' cw'D w/mosx 17 1/2" HOLE NICOLA! CREEK PROPOSED ~0 PCF I~D #5 SPUD MARCH 19, 1967 Ci~ENTIR.UGFROUBO0'TOSURFACE aN(a.E: S'I'~G 2 3/e-. 4J~. N-BO CBdENTPt. UGFROId2.qOO'T01700' 2 ~ 1gO0' -- 1~30' (NOT IN ~ 13 ~/8',. s,(..~L · 20ol, CUt"D ~ITH 1770 SX 2 SI'F 2005' - 2020' 2 ~ 2201' -- 2238' 2 SFF 2302' - 232~ ~ WtTH 2~0 SX CEUE~ P~.UO Fl 2517' MINIMUM 2" KILL LINE WITH (2) 2" 3M VALVES i. d; KILL LINE FROM MUD PMP & CEMENT UNIT CONTRACTOR PROVIDE OPERATOR PROVIDE BELL I NIPPLE 13 5/8 ,3000 PSi ANNULAR i FLOWLINE BLIND RAMS I PIPE RAMS I I I SPACER SPOOL SINGLE GATE 3M 1;3 5/8 5M FLANGE 3" CHOKE LINE WITH ONE REMOTE &: 1 MANUAL .5" 3M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) SINGLE GATE 3M 13 5/8 5M FLANGE ADAPTER FROM 13 5/8 3000~ FLANGE I'' I 1,.3 5/8" 3M BOPE STACK NICOLA! CREEK #l-A, 2, 3, 4 UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) RECEIVID ~ -.'-,-..., OJ/&.Gas Con~ SCALE: NONE DATE: 6/7/91 DRAWN: GRB TO WORKING PITS ¢ ' HYDRAULIC ACTUATED CttOKE PRESSURE GAUGE TO BOPE , MANUAL CHOKE Environmental Group Alaska District Unocal Oil & Gas Divisi Unocal Corporation P, O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL September 27, 1988 Hr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Comm. ~OO1 Rorcupine Drive Anchorage, Ak. 99501 Dear Hr. Chatterton- Nicolai Creek Well No. 3 deliverability Test This is to advise the Alaska Oil and Gas Conservation Commission that Unocal proposes to vent or flare approximately ~HHCF of natural gas over a 24 hour period during a deliverability test on Nicolai Creek Well No. ~. It is Unocal's intention to flare during this test, however, due to equipment availability and short duration of the test, venting may be our only alternative. Unocal will submit Form 10-422, Producer's Report of Gas Disposition as required by 20 AAC 25.2~5 after completing the deliverability test. Should you have any questions, please contact me. ruly yours, navn]d'_~~pdecialist attachment cc: Navin Sharma Steve Wiese COOK INLET ALASKA BAY WEST FORELAND (GA SI REDOUBT SHOAL AREA MOQUAWKIE N/COLA/ ~_ P ~RAN ITE POINT TR, eOING BAY MIDDLE GROUND . .. Ko$iiof CREEK Ninllchtk FORK Willow Il Jonet, vllla II Palmer onueko · o :.ktut~ RIVER NO. COOK INLET River NCHORAGE BIRCH HILL (O/LJ oBEAVER CREEK (GAS) WEST FORK O~4S) STERLING RECEIVED S£P 2 8 ]988 Alaska 0ii & Gas Cons, Commissio~ 0 I0 ZO ~ :MILll 0 OIL and/or GAS FIELD · TOWN EXISTING PLATFORM ZOO' DEPTH CONTOUR ., EXHIBIT A STATE OF ALASKA ALASKA ~.,L AND GAS CONSERVATION CC,aMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX] OTHER 2. Name of Operator . 7. Permit No. Texaco .U,S.A. 67-7 3. Address P.O. Box 4-1579, Anchorage, Alaska 99509 4. Location of Well 1955' S/N, 1636' E/W Line Sec. 20, TllN, R21W 5. Elevation in feet (indicate KB, DF, etc.) _262 KB (_or 246 Grd. Level) 12. I 6 . Lease Designation and Serial No. A-034161 8. APl Number 50- 283- 20003 9. Unit or Lease Name Nicolai Creek Unit 10. Well Number 3 11. Field and Pool Pool "B" Nicolai Creek Gas Unit 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 [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other EX] 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 starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request approval to discontinue submitting forms 10-405 "Monthly Production and Injection Report" and 10-422 "Producer's Report of Gas Disposition" as the above well will remain shut-in until there is a demand for natural gas.. RECEIVED MAR 1 1983 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregO%is tr~e and correct to the best of my knowledge. Si.ne The space below for Commission use~/ Conditions of Approval, if any: Approved by ORIGINAL-SIGNED' l~Y [Ot~HIE C. SMITD' Title District Manager Date March 9, 1983 Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" !n Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLI..--I WELL~Id OTHER 2. NAME OF OPERATOR Texaco Inc. 3. ADDRESS OF OPERATOR P. O. Box 4-1579, Anchoraqe, 2~laska 99509 4. LOCATION OF WELL Atsurface 1955' S/N, 1636' E/W Line Sec. 20 TllN, R21W 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 262 KB ( or 246 Ground Le~e!) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. A 034161 7. IF INDIAN, ALLOYTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Nico!ai Creek Unit 9. WELL NO. 3 10. FIELD AND POOL, OR WILDCAT Pool "B" 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 20, TllN, R21W 12. PERMIT NO. 67-7 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING I I FRACTURE TREAT L------[ MULTIPLE COMPLETE I I SHOOT OR ACIDIZE ] ~ ABANDON* REPAIR WELL 'Ir----Il CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING · SNOOTING OR AClDIZlNG ABANDONMENT* (Other) Cl.~anout and Test , (NOTEz Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detall~, and give pertinent dates, Including estimated date of starting any proposed work. PURPOSE t To blow well, and attempt to olean o~t sand-oF water preventing' production, and run pressure 's,u~.veys. 1.Riggedup wire line unit and ran !-29/32" feelem to 2192'. Ran pressure bomb to 2192'. Open well to,aim an.d blew for 1-1/2 h~s to clean up well. TP.642 psi, ~LP 638 psx Sh%it xn Overnight 9/27/79 2.Flow test 9/28/79: SI· Press. 739/741 psi 2 hrs, 1/8" choke,. 728/720 psi, 271 mcr/d, clean 2 hrs, 3/16" choke 710/712 psi, 607 reef/d, clean 2-1/4 hfs, 5/16" shoke 630/641 psi, 1483 mcf/d,clean 2 hrs. 3/8" choke 598/641 psi, 2005 mcf/d, clean SI 3 hrs. 733/733 psi 3.Pressure Survey attached. Ancr~orag~ 16. I hereby certify that the_foregoing is true and correct ~;. y.' ~'arme~r · - (This space for State office use) . TITLE General S~pe~intenden%ATE APPROVED BY CONOITIONS OF APPROVAL, IF ANY'- T IT LE DATE October 11, 1979 ,. See Imtructions On Reverse Side :33 1.00 1.25' '1 ..50 1.75 2.00' .:!.. '.- 3-'00 .: ..~ 5.00 7 ,' 0.0 . ~_ 9~:Oo. ~::., : -- i'%.00'.: ,9:18- --09: Pressure Top Inst 874 868 872 829 815 810 8O5 803 804 804 803 855 868 873 874 874 874 874 874 875 875 875 876 876 876 876 870 867 867 866 866 866 865 865 868 852 849 847 847 RB,-CEIVE OCT 1 9 !97g (PSIG) Bot Inst 886 : 881 882 841 826 818 815 813 813 813 813 ~.64 881 884 885 " 886 888 887 887 888 888 888 888 89O 889 89O 882 880 8?9 8?8 8'/8 8?6 Alaska Oil & Gas A. HALLIBURTON Comp~Chora.qe 876 876 881 864 860 859 :oo :0.5 02:05 04:05 !<"06:05 -'. ' 14.00 .: .. ' 07:3S' ::~' ' 15:50'-~' "':' · 6,00 8.00~ 10: 00 12:0.0 'ALASKA 99611 Page 2 Pressure (PSIG) Top Inst Bot Inst 847 859 847 859 847 859 ' 847 '~,z',,. - 859 858 871 797 810 773 782 763 774 764 774 766 777 768 779 771 781 773 783 773 ~3~ - )'/.f 783 806 ...816 746 ' 759 720 729 733 742 741 753 746 757 747 757 747 . 757 747 '' 757 843 853 866 878 870 882 872 884 ~872 886 873 886 873 887 873 888 876 889 877 891 878 892 878 892 879 892 879 892 879 .... " 892 ()CT ! 9 gTg fiio.$ka 0i: :3. Gas Coils, Anchorage Form 10-403 REV. 1-10-3'3 Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O,L I--1 GAS [~] WELL'' WELL OTHER 2. NAME OF OPERATOR TEXACO, INC. 3. ADDRESS OF OPERATOR P.0. Box 4-1579, Anchorage, AK 99509 4. LOCATION OF WELL Atsurface 3369' N, 1668' E, from SW corner Sec. 20-11N-12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 189' G.L., 205 K.B. (MSL) CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: PULL OR ALTER CASING MU LTl PLE COMPLETE ABANDON* CHANGE PLANS 14. TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 5. APl NUMERICAL CODE 50-283-20003 6. LEASE DESIGNATION AND SERIAL NO. USL AN 034161 ;7. IF INDIAN, ALLOI Y'EE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Nicolai Creek 9. WELL NO. 3 10, FIELD AND POOL, OR WILDCAT Nicolai Creek Gas SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 20-11N-12W, S.M. 12. PERMIT NO. 67-7 )ort, or Other Data SUBSEQUENT REPORT OF-' WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Gas Product~ REPAIRING WELL ALTERING CASING ABANDONMENT* est (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 20" 7" Well Status' T.D. 8841' csg @ 282' liner , plug @ 2522' 13-3/8" @ 2001' 1941-2522', 2-7/8" tubing tail @ 1908', no packer. Shut in @ 735 psi Oct., 1977. Perforations 1900-30, 2005-20, 2201-38, 2302-28, 2360-80. Work Done' Moved in 9-25-79, ran Produced on 1/4" choke for 2 41o Ran 4-point test as-foll in with feeler gauge, found top of fill @ 2192' hours to clean up' 1018 MCF/D rate, 666/667 psi, ows, with pressure bomb @ 2188' 1/8" choke, 271 MC,F,/D, 40o 3/16" ", 607 , 30°', 5/16" " , 1483 " , 41°, 3/8" " , 2005 " , 420, 728/730 p,s,i, 2 ho,u, rs Trace mud. 710/712 , 2 Clean 630/641 ", 2-1/4 hrs. Clean 598/614 ", 2 hours Clean After test, pressure built back up to 733/737 psi in 3 hours. Test complete 9-28-79. See attached pressure bomb recording. ~'~IV!:D OCT 1 7 1979 16. I hereby certify that the foregoing is true and correct SIGNED~ TITLE Alaska 0it & O, ,~ ........ , ..... L.. ,,r,¢ Anct~u~age District Land Rep. DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side P.O. BOX 'N' KENAI, ALASKA 99611 AREA CODE 907-283-7531 Texaco, Inc. Nicolai Creek #3 Granite Point, Alaska Date 9~/79 .O~ well, sit in lubricator Gradient change On bottom Gradient change Out of hole in lub. Unload well' Shut in well, RIH On bottom Open well through 1/8" choke Shut in Well Open well through 1/4" choke Shut in well 9/27/79 Open well through 1/8" choke Time 11:06 11:21 11:43 11:45 12:00 12:02 12:15 12:20 12:50 13:05 14:17 14:28 14:33 14:48 15:03 15:18 15:33 15:48 16:03 16:18 16:33 16:48 17:03 17:18 17:33 17:48 18:03 18:18 18:33 19:33 21:33 23:33 01:33 03:33 05:33 07:33 07:48 08:03 08:18 Otis Engineering Corporation Buildup Flow Time .00 .50 .00' .15 .00 .25 .50 .75 1.00 1.25 1.50 1.75 2.00 .25 .50 .75 1.00 1.25 1.50 1.75. 2.00 3.00 5.00 7.00 9.00 11.00 13.00 15.00 .25 .50 .75 Top gauge 2178 MD Bottom gauge 2183 MD Pressure (PSIG) Top gauge Bot gauge 745 745 778 872 874 780 745 745 650 847 874 868 872 829 815 810 805 803 804 804 803 855 868 873 874 874 874 874 874 875 875 875 876 876 876_ 876 870 867 867 750 750 793 880 88O 784 750 750 654 858 886 881 882 841 826 818 815 813 813 813 813 864 881 884 885 886 888 887 887 888 888 888 888 890 889_~ 890 882 . A HALLIBURTON Company P.O. BOX 'N' KENAI, ALASKA 99611 AREA CODE 907-283-7531 Texaco, Inc. Nicolai Creek #3 ~ranite Point, Alaska Date 9/27/79 Shut in well Open well through 3/16" choke Shut in well Open well through 5/16" choke Shut in well Open well through 3/8" choke Shut in well Time 08:33 08:48 09:03 09:18 09:33 09:41 09:56 10:11 10:26 10:41 10:56 11:11 11:26 11:41 11:45 12:00 12:15 12:30 12:45 13:00 13:15 13:30 13:45 14:00 14:05 14:20 14:35 14:50 15:05 15:20 15:35 15:50 16:05 16:20 16:35 16:50 17:05 17: 20 17:35 Otis Engineering Corporation Page 2 Buildup Flow Time Top gauge 2178 MD Bottom gauge 2183 MD Pressure (PSIG) Top gauge Bot gauge. 1.00 1.25 1.50 1.75 2.00 .00 .25 .50 .75 1.00 1.25~ 1.50 1.75 2.00 .00 .25 .90 .75 1.00 1.25 1.50 1.75 2.00 2.25 .00 .25 .50 .75 1.00 1.25 1.50 1.75 2.00 .25 .50 .75 1.00' 1.25 1.50 866 878 866 878 866 876 865 876 865 876 868 881 852 864 849 860 847 859 847 859 847 859 847 859 847 859 847 859 958 871 797 810 773 782 763 774 764 774 766 777 768 779 771 781 773 783 773 783 806 816 746 759 720 729 733 742 741 753 746 757 747 757 747 757 747 757 843 853 866 878 870 882 872 884 872 886 Alaska tJi! & ~.:...~ ~ : A HALLIBURTON Company ,,~hula{j~ P.O. BO× 'N' KFNAI, ALASKA 9981 AREA CODE 907-283-7531 Texaco, Inc. Nicolai Creek #3 Granite Point, Alaska Date 9/27/79 9/28/79 POH Change in gradient In Lubricator T~me Buildup Flow Time Page 3 Top gauge 2178 MD Bottom gauge 2183 MD Pressure (PSIG) Top gauge Bot gauge 17:50 1.75 873 887 18:05 2.00 873 888 20:05 4.00 876 889 22:05 6.00 877 891 00:05 8.00 878 892 02:05 10:00 878 892 04:05 12:00 879 892 06:05 14.00 879 892 07:35 15:50 879 892 07:37 780 787 07:47 744 750 Otis Engineering Corporation A HALLIBURTON Company .. ~;~:"~"'-' ............. (Other instructions DEPARTMEN'i' OF THE INTERIOR ~,,,~,~ GEOLOGICAL SURVEY ~ SUNDRY NOT!CES AND REPORTS ON WELLS (Do not ~:::-this form for propo, als to drill or to deepen or plug back to a different reservoir. < .--,' Use "APPLICATION FOR PERMIT "for such proposals,) Form approved. ........... P. dg_~L~m"_e_a~ _.~_%.a_~:3~!~ ?_!.. 5. LEASE DESIGNATION AND SERIAL NO. A-034161 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7. UNIT AGREEMENT NAME oi~ [-] GAS ~ OT~ER _Nico_!.._ai___Qr_e_e~k__UnLt_ -" WELL WELL 2. NAME OF OPERATOR 8. FARM OR LEASE NAME TEXACO Inc. 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 4-1579, Anchorage, Alaska 99509 4. LOCATION OF. WELL (Report location clearly and in accordance with any State requirements,* See also space 17 below.) At surface 1955'S/N, 1636' E/W line, Sec. 20, TllN, R12W, S.M. 10. FIEI~D AND POOL, OR WILDCAT Nicolai CreeP~°~n~"- 14. PERMIT NO. I 15. ELEVATIONS (Show whether DF, RT, GE, 67-7 [ 262 KB (or 246.Grd. Level) ~6. Check Appropriate [lox To Indicate Nature of Notice, Report, or Other Data 11. SEC., T., a., M., OR BLK. AND SURVEY OR AREA Sec 20,TiiN,Ri2W 12. COUNTY oE I'A~aSn "lJ~. '~'r:,r,~: ..... Kenai Bot. Alaska NOTICE OF INTENTION TO : FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT t ALTERING CASIN(; SHOOTING OR ACIDIZING ABANDONMENT* i '--J' (Other) ~ -. (NOTE: Report results of multiple completion on Completion or Recompletton I{eport_![~._d_Iyj,.~__~!)~.r.l!}~! .............. 17. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, ,%nd give pertinent dates, including estimat~,d date of starting any proposed work. If well is direct(anally drilled, give subsurface locations and measured and true vertical depths for all markers and zom,s l-;rti- nent to this work.) * F. M.Ltndsey & Associates surveyed the elevation of Nicolai Creek . Unit No. 3 on January 25, 1972 and found the "as ,built" elevation. of the top of the bolt on the top flange of the wellhead at 247.02 ft. above sea level. Ground level elevation would be 246 ft. KB elevation would be 262 ft. 18. I hereby certlf~ th~h--e--~regol!~ issue and correct T,~ M~Cann Field Foreman an ¸ 1/28/72 TITLE DATE (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Instructions on Reverse Side Fo~m REV. ~ il~: [.. AP1 N~CAL CODE OIL AND GAS CONSERVATION; C.O~%M4TTEE 3 eNg /~ 50-283-20003 4 ~-, ~'-~ f~: LEA~]~ D~/GNATION AND ~LA~ Nd). SUNDRY NOTICES AND REPOR?$ ON ~ .... USL A-034161 (Do not use this forra for proposals to drill or to deepen or plug back to a ~ Use "APPLICATION FOR' PERMIT--" for sUch proposals.) WELL WELL __ '~'[ I~'~E 'OF OPEP,~TOR ~---~.!~-~- D~V ~'-~~-'' · UNIT, FAI~VI ORaL,EASE NAME ~ .... ~;'~,F,~-"'i--'~Nioolai Creek Unit · I u .! ~ I .I ' : 3~ ADD.SS OF OP~TOB P.O. BOX 4-1579,. ~choraqe, Alaski~',~-~]~3 , ~ O~ ,~r" ~ts~fa~"1955' S/N, 1636' E/W line, Sec 20.~' -' ' ' ' - "B . * t 11. S~., T., R., M., (~M R12W, S .M. ~ Sec.20~gll~R12~S.~. 1~. ~VA~O~8 (Show whether D~, ~, GR, e~e. ~I~. ~ ~O. ' 200.' ~ Gr. ~ ~7-7 C~k A~m~ia~ ~x To I~*e Nature ~ ~tlce, R~, ~ ~ '~ NOTICE OF INTENTION TO: TE~T WATER 8IIUT-0FF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WaLL PULL OR ALTER CARING MULTIPLE COMPLETE ABANDONs CHANOE PLAN8 SUBSEQUENT IK~PORT OF: FRACTURE TREATMENT AL'~ERING CARING 8HOOTING OR ACIDIZING ABANDONMENT* (Other) LoCation Correction (NOTE: Report results of mqlttple completion on Well (Other) Completion or Recom~letion Re~)ort and Lo~ form.) -1~. DE~R-~BE 'I'ROPOEED OR COMPLETED OPERATIONal (Clearly state all pertinent details, and give pertinent dates, including estimated date of startin~ an}' proposed work. The corrected "as built" surface location of subject well is 1955' S/N line, 1636' E/W line,. Sec.20, TllN, R12W, S.M. as shown on attached survey plat. 16. I hereby c.r t%fy th~the f~_regotng l~ tr~_~et Sl~D ---~~ ~'-,'~ ~.. TX~',E Field Foreman VATEOCt' 22, 19 71 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See Instructions On ReVerse Side A.'~I · COD£ · 50,283-20003 Re lease Date 6r4r69 ..... State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Pet roleum 8ranch INDIVIDUAL WELL RECORD Sec. 20 ,1,, : ~ - _ _ T. 11 N R. 12 W S Meridian Permit No. 67-7 Issued 3-7-67 ,. Operator Texaco-Inc. Lease No,' - AN-o3~i61'- ' or Owner Nicolai Creek Unit Location (Surface) Loc. (8ottom) 1911' FSL & 1668' FW-L Sec. 20 , ,,,~ _ , , , ,, , · ,_ _ , ~ ,, j .... Spud Date .... 3/19~67 :.. .D?illing Ceased ~ ,~ 5--4-67; ........ Abandoned Total Depth 8841 Elevation 200 Completed (F-GL-P)._ ...... .5-~:.6.7, ,. _IP__ -_ _B/D, Gray .- APl Cut ~ Ga%_ 3,56,0,.... MCF/D, Bean 2.8/64 CP.._. .,,_ psi, Casing: Size Depth__ SXCmt. pe, rf: 2007- 2020'; _ 2201~-38~; 2302'-28~; 282 ' 720 2360' =80',;, 1900'-30' 13 3/8" 2001 ' 1770 .... 7" liner 1941'-2522' 220 TP ............ 72_5_-_ _ -_ _ ps i ......... _. ..... _ , _7_2,0,0'-71_0,.0' (est) 50 Sx. . _, _ ~_, .... -_ . 5000'-4900' (est) 50 Sx. _._ .___..lO_O sx. GEOLOGi C FORMATIONS Surface Lowest Tested ,,, · ...... .~._ ..... _ ........ Name PRODUCTIVE HORIZONS , ~ _Depth Con ten ts ~_~ ..... , , ,, _, ~, _ . d., . , - _ _ WELL STATUS Year Jan Feb, Nar ,Apr May June July Au9 Sept Oct Nov Dec .... __ .-.....: . .. : _. __ . ' "-'.' .- ' . _. .. _ _ '- 'J -- · -_ - -- -- ~ _ - - _. -L!~.' . - : .. -- 'j _ -_ L _ . _ .,~_'.; ,--, _ - ' ~LL~- ' .? _ . S.T. 69..09' '_-7.3.92.' Zeavin~ lO 73/4"._D..Cs .in :hole..~ ... ...... .... :-- Retest_ witne~sse.d._ by_ W;_.. WU.~!c. ke, _,O.. S. G_....S.. Remarks: Contractor: Reading & Bates Drilling Co. Form No. P--4 ,REV. 9-30-6~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF =DRILLING AND WORKOVER OPERATIONS SUBMIT EN DEPLICA~E WELL -- WELL 2. N~/~E OF OPEI{ATOR Texaco Inc. 3. ADDRESS OF OPEI{ATOR OTHER Box 664 - Anchorage, Alaska 99501 4. LOC'ATION O'F WF, LL 1668'E and 3369'N of SW corner Sec.20 ·API NU~ERICAL CODE 6. LE3~SE DESIGNATION AND SERIAL NO. USL AN 034161 7. IF INDIAN, ALOTTEE OR TRIBE NAME ~6d I~fi Creek /'9. %~LL NO, ~ Un~ 3 10. FIELD A_ND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M.. i BOTTOM HOI~E OBJECTIVE) Sec. 20 TllN-R12W 11~. PEB2VlIT NO. 67-7 13. REPORT TOTAL DEPTH AT F_d~D OF MONTH, CId-A_NGES IN HOLE SI~E, CASING A/NrD C~WIENTING JOBS INCLUDING DEPTH SET A_N]) VOLUATES USED, PERFORATIONS, TF_~TS A!NqD I{ESULTS. FISHING JOBS, JLrNK IN HOLE A2qD SIDE-/qlACKED HOLE AND A.NY OTHER SIGNIFICANT CI-IANGES IN HOL~ CONDITIONS. Well shut in since completion RECEIVED PlVi$1ON OF MINES & MINERAt~ ANCHORAGE 14. I hereby certif~ tl~t the ~or.r.r.r.r.r.r.r.r.~' g is tj~d correct .~-/~~~.c. /_~f~___~ Asst. Superintenden~A~,: 2-29-68 , / / "~ _ (/lTE--RePort on required each month, regardless of the status of operations, anO re,st ~e fJle~ form t~is for calendar wTth the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Form No. ~4 STATE OF ALASKA svs~r iN nEI:'LICATE O}L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS oz~ F--! ~s ~ WELL L_.J WELL OTHER · .. NAME OF OPERATOR TEXACO Inc. A~RE~S C~r orrr~o~ .... P. O. Box 664 -Anchorage, Alaska 99501 4. LOCATION OF WELL 1668'E and 3369'N of SW corner Sec. 2O %~ API'NUiN~EI:tICA]L'CODF.' ' O. LEASE DESIGNATION AND SEEIAL U.S. L. AN 034161 '7. IF INDIAN, ALOTTEE OR TRIBE NAME 8. LrNIT,FA.I~M OR LEASE NA~.ME Nicolai Creek 9. WELL NO. Unit %3 10, 'FIEJ-~ 'A~'ND' POOE." OR 'WILDCAT Wildcat "iL SEC., T., R., M.. (BOSOM HO~ O~~) Sec. 20 TI~-R12W 12, PER,MIT NO. 67-7 , · , 13. REPORT TOTAL DEPTH AT END OF MON7~I, CHAiVGES IN HOLE SI~..E, CASING ANT) C~'MENTI~G JOBS INCLUDING DEPTH SET AND VOLLrMES USED, PERFORATIONS, TESTS A3~D RESULTS. FISHING JOB~, JU/qK iN HOLE AkqD SIDE-TI:La. CKED HOLE AND ~NY O~R SIGNIFICAINrT CI-IA~S IN HOL~ CONDITIONS. Well shut in since completion RECEIVED JAN 196 t DI¥1,510N OF MINES & MJNERAkS ANCHORAGE ~ ~~~~___~.~ Field Foreman ~./. i- ~[ ~a~r ' -- ,, , T~TI~E ..... DATE . ~ i Ul ii i i i iliiiiii I i N0~--Report on this form Js required for each calendar month, regardless of the status of operations, Division of Mines & Minerals Dy the 15th of the succeeding month, unless othe~ise directed. January 5, 1968 Form No. P--4 P.~EV. STATE O,F ALASKA O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS _ WELL L__J WELL OTHER 2. NA~VIE OF OPERATOR T~XACO Inc. ~. AD~I~ESS OF OPERATOR SUBMIT IN DEPLICATE AP1 NUA{ERICAL CODE LEASE DESIG-~'ATION A,~'D SERIAL NO. UaL AN 034161 ?[ IF INDIAN, ALOT/EE OR TI~IBE NA~IE 8, LrNIT,FA3LM OR LEASE NA.ME Nicolai Creek 9. WELL NO. P. O. Box 664- Anchorage. Alaska 99501 4. LOCAq~ION OF WELL 1668'E and 3369'N of SW corner Sec. 20 Unit #3 10. FIELD A_ND POOL OR WILDCAT Wildcat 11. SEC., T., R,, 1%{., (BOTTOM HOLE Sec.20 TllN-R12W PERbIIT NO, 67-7 23. REPORT TOTAL DEPTH AT END OF MONTH, CFiA/~GES IN HOLE SI~E, CASING ANT) CE1V[ENTING JOBS INCLUDING DEPTH SET A/WI) VOLU/VIF_~ USED, PERFORATIONS, TESTS A/%TD P~ESULTS, FISHING JOBS, JLrNK IN HOLE A-~D SIDE-~CF~ED HOLE AND A/~Y O3Vz~-~ SIGNIFICA/~T ~ES IN HOL~ COI~DITIONS. Well shut in since completion 14. I hereby certify t , SIGNED .._,~'~/--~'~'~~TITL,E Fie ld Foreman DA'rE December -;4, 19 6 7 N~E-~eport on thi, form i, required for each calendar month, r~gardle55 of th~ status of operation% anO m,,t ~ fileO i, d,,licat~ with/~~ivision of Mines & Minerals by the ~Sth of the succeeding month, unless othe~ise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LA.D or~,~E Anchorage LE^sE NuM.E.ANO 34161 LEASE OR LJN/T NA~E Micolai C~eek LESSEE'S ~ONTHLT REPORT OF OPERATIONS The followir~ is a correct report of operatior~s arid prodtzetior& (inel~dir~ drillir~ and prodtzoin~ wells) for the rnontY~ of ~TOB~ 19 67 _ ., .. ~. -6~---'i~'//---~ ........................ '-~ ................ O----t~'~'~'~':'~ .............. .~enr s address ................ ; ................. j, ............................... c;orn, pa~y__~c~)~~~ .~,~,_, . _~.._ , ......... g. O. Box 664 ~.~ -J~./~. ~a~r--'-~--~-- .... ' ...... , ...... ~Y~ui;{~-~ ........................ ~ ................................ ~~-------- .................................................... e~o.,e .................................................. , .... ~ ........................... ~e~t's ~le ..... _~_%_.e_~_~__g.?_~_.e_..m__a._n.. ................. SEC. AND NICO~I Z] Well sh~ = Tw] WELL NO. ,qIT 3ce DAYS ~3 corn BARREL8 Or O-. ,letion. {lin &F Cu. F~. oF GAS (In' thousands) OALLONS OF GASOLINE RECOVERED BARRELS OF none, so state) RE]~IARKS (If drilling, d~Dth; date and reeult of test for content of ga~) NOTE.--There were no runs or sales of oil; no M cu. ft. of gas sold; no runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--ReportduplicateOn this form is required for each calendar bym°nth' regardless of the status of oper_atio. Ds,.~anll be filed in with the Division of Mines & Minerals the 6th of the succeeding month, directed. NOV 3 1967 DIVISION OF MINES & NflNERAL~ ANCHO~ Form No. P--4 ~ -" STATE OF ALASKA · OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAN° ~r~,c~ Anchorage, L~ASEN''M.~. AN 034161 LEASE OF~ UNIT NA~4E N±¢olai O~eek LESSEE'S MONTHLY REPORT OF OPERATIONS TAe followin~ is a correct report of operations and production (ir~el~din~ drillir~ff and prod~oir~ff w e l l s ).4 ~e r~ t s a d d r e s sf ° r t l~ e rn o n t hi ~_ ._ _ _ _O_ _._ , _ __B__Q~__ _6___~_ ~_o f .... __S__~_~__t___e_~__~__r__ ................ 19__6__7__, _ ........................................................................ .... ................................. Company Tex:~~~~Xn. A~chorage, Alaska 99501 ......... si ne(t ................ .................................. SEC. AND BAEEEL~ OF OIL (]EAVITY (~ASOLINE WATER (If (If drlllinw, depth; if shut down, ~ or ~ Twr. RANGE WELL D-rs Cu. FT. OF (]AS GALLONS Or BARRELS o~' REMARKS NO. PROD~'C=D (In thousands) ~ ~d r~ult of t~t for - R~COVrR~V none, so state) eon~t of ~) .cola/ Cr~ek Unit ~3 I ~11 shut Ln sinc~ completien ............ NOTE.--There were ............................ ~.~. .............. runs or sales of oil; ......... ..n.o.. ................................ M cu. ft. of gas sold; .......................... ~ ............................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of~p~ja~j~o~, It.sb be filed in duplicate with the Division of Mines & Minerals by the 6th o~ the succeeding m .o~h[~u~!e~ directed. O[ 'l b I967 DIVISION OF MINES & MINERALS Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAN° =r~,=~ Anchorage L~A~ N"M~£. AN 034161 LEA~E =. UNIT NAME N±cola£ Creek LESSEE'S MONTHLY REPORT OF OPERATIONS Stau' ....... _A_:_l_a__s___k_.~ ................... Borough ........._K._~D._~_.% ................... Field ....... ~_ % g..0.~_~_~ .__.C_~_.e.~.g. ................................ TAe followir~ is a eorreo~ repor~ of operatior~s and prod~etion (ir~el~dir~ drillir~ and prod~ei~ wells) for the month of ............ _~___u__~i.u__s__~_ .............. ,19__.6__7, ............................................................................ ,/l ~e~ t's address ........... ~_~___Q_e___J~_Q~f._:_~_~__4 ......................... Com, pa~ y .... -~t~-~'~rl~"~ C'~/~-- -'~x._z ...,~/...~r~__~...~. ~ ............... .................... ................................ .... ................ e~on~e ................... _%!~__-_k4___8_~_ ............................................ .~e,~t s u~ .... ~_~_ _e_ %~ _ _ ~_ _o_ r_ _e_ ._m_ _a_ _n_ _ ................. SEC. AND TwP. RANGE WELL Days BAaRErS Or OIL (]RARITY CU. F~. or GAs GA~oNs or Ba~az2 or REMARKS ~ O~ ~ No. Pao~o~ (~'tho~) GASO~NE W~T~R (If (It ~n~, depth; if ~hut d~n, oa~: - RECOVEreD none, so state) ~te ~d r~ult of trot for g~e oo~t o~ :O~I CRE:~ INIT ~3 ~1 sht~t i]~ since com[letion We] NOTE.--There were ................. ..I)...O. ........................ runs or sales of oil; ........lq.O ................................. M cu. ft. of gas sold; ................ ~.0. ...................................... runs or sales of gasoline during the month. (Write "no" where applicable,) NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicat~e with the Division of Mines&Minerals by the 6th of the succeeding month, l~nl~es~,,ot~her~w~iste directed. K !:: LI: IV SE? 11967 DIVISION OF MINES & MINERAL~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LANO -r~,CE Anchorage LEASE N"MBE. AN 034161 LEASE OR UNIT NAME Nicolai Creek LESSEE'S MONTHLY REPORT OF OPERATIONS Kenai Nicolai Creek State ____~_p._~__o_~__~_ ...................... Borough Field TAe followir~ is a correot repor~ of operatior~s arid prod~etio~ (i~el~di~ drilli~ and prod~ein~ wells) for the month of .......... ~_u__l.~ ....................... ,19__6_.7_, _ ........................................................................... ~exl,~, 8 (3C~l,l' 88 .................................. ~ ............................................................. Anchorage,, Alaska 99501 ....................... ............... .................................... -'""-- Phor~e ................................................................................... SEC. AND BARRELS OF OIL OEAVITY (~ASOLINE WATER (~J' (If ~11~. depth: if shut d~n, o~; ~ OF ~ TWP. ~RANGE WELL D~rs CU. FT. OF OAS OA~ONS O~ B~ O~ RE~ARKS NO. PRO~O~D (~ th0us~) ~te ~d r~ult of trot for RECOVERED none, so state) e~t of ~) Guly 6, 196; - Per{orme~ 4 POinl' Production ~es2 wit:nessed by Nr. ~unr.icke of the II. 8. G.S. Pro(~uced a~: variotts rates 250~t~t~' :tal, to the atmosphe] e. I NOTE.--There were ....... ~..O. ................................... runs or sales of oil; ................. ..n...0. ........................ M cu. ft. of gas sold; ..................... ..~...O.. ................................ runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th of the succeeding mo~)h,~u~es~ cltl~e~,wl~er~ directed. AUG 3 1967 DIVISION OF MINES & MINERAL~ ANCHORAGE GAS 'LL OPEN FLOW POTENTIAL TEST . 4-POINT TEST Test Initial :~ Annug] ~] Special Field Reservoir i Test Date Nicolaz C,~ee~ Upper ~<ena~, ~0u!~ 6, i~c, Operator Lease [ JVell ~o~ ~'~CO Inc. U8~ ~0 34161 ~ ~io. ~ ('ounty Producing Thru TBG. I CSG. T]3G. Size Location Completion Date Peninsala Bo~ ough P, eser~'01r [ Wdlhead Temperature Temperature Gn~-Liquid Hvdr3:~ari;o t [ Gravity of tlalio M(F per Bbl. ~ Li,iuid [ADi) Pipeline Connection Type Taps at~.;~o~p.here Cz itical If'low IPz'over .Alu]tiple Completion (Dual or Trlple) Type productfon front each zone S~9.1e Complo~ion Dry Gas OBSERVED DATA Flow Data , , Time (Prover) (Choke) } Press. Diff.Il Tubing Casing Flowing of Plow (Line) (Orifice) h I Press. Press. Temp. Hours Size Size psig xvt psig psig °F .. 2 - , 9'13' j ¢ 12. ~ 13 - ~ ~. 1/2 ,...,.. ,. 747 747 815 ~ 47 -- . . . , .. ,'so ,.:..'~, ! Jt i/4 ~-~c~l~c~io.~ 89:[ ~ Coeffi- ~O~ Gravity Compress. No. [ eient ~w PPressure F~ctor F~ctor Rate of Flow (2~ Hr.) m psia g pv Q }iCF/D ~. 2 6, 51. ,S97 17.02 ........ 1 ' t~ ~7 ..o "--$ 2. 5 ....................... ~---~=~r=.,. ~ ~ ................................ I.*-":7 ........, '..}=~,'¢'~ ........................ .... i ' ............. ' ....3o,.," ~*-" ~. 44 ,._::.,.::~7' , ,,. 12.07 1 ~/,/:Ii :f~ PRESSURE CALCULATION~ 4, ~ICF/D . ~3 CERTIFICATE: I, the undersized, state that I am theFiel~ ~Or ~ t' ~~0 IB:C~ (company), and that I am authorized by said company to make this report; arid that this report was pre- pared under my supervision and direction and that the facts s.t~o.f.~d therein are true, correct and complete to ,,? % ~, , ~;; ~x,¢' , the best of my lmowledge. Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Poin~ Test) Form Authorized by Order bio. Effective October 1.~ 1~58 Choke ~, 1/4 ~' OPEN FLa- POTENTIAL TEST - NICO~I ~-..:EEK b~IT ~3 !O~U 897 39 1025 885 42 i029 883 42+ 1035 ~2+ 43 ~u4~ 882+ 43+ 1047 882 + 44 1050 P casing 885 psig 1054 882+ 44 Choke I/8" %? 1056 1057 II00 1109 1115 1118 1119 l~2z 895 45 897 45 900 45 900 45 903 P casing 900 45 9OO 45 Change 'to 1/2" ~_¢ 1122 1129 782 42+ 1132 766 42+ 1136 752 44 1140 747 46 I145 748 46+ i!5! 747 47 ].156 747 47 .ti59 P casing 815 1201 747+ 47 1231 1233 12 '~ ~ 1243 1247 Bean 3/8" Tirade 1250 1253 1255 1257 1259 I300 130~ 1308 P casing ]310 1312 1229 Opened on 3/8" Prover 3/4" 865 858 85O 85O 850 Shut in to change Prover to 1/2" Prover W,e!l Head,'. Opened 86O 856+ 853+ 851 85O 85O 856+ 426 psig 85O 1316 Opened 1/4" bean Prover also 1/4~' 1339 712 1320 890 1325 892 133'7 891 Casing pressure 893+ 25OF 32° 30° 34° 36° SI 1.~':~ Build up to 901 psig at 1347 906 psig at 1351 L=2140' 1/4 1/8 1/2 1/2 1/4 NICOLAI CRE~ NO. 3 BACK PRESSURE CURVE FROM CSG PRESSURE G=. 575 Z=~. 88 Ta=77© Tc=355 Pc=675 Pwhs=928 Pbhs=973 psia Ta 535 535 536 Pa Ti Pz Z GSGP eGL/53'3ZT BHPF 920 1.51 1.36 .88 900 1.048 943 938 1.51 1.39 .88 918 1.048 962 858 1.51 1.27 .88 830 1.048 870 525 891 1.48 1.32 .88 871. 1.05]. 915 530 929 1.49 1.38 .88 908 1.049 952 1/4 1/8 1/2 1/2 11,~ p2BHF p2BHS 8.89 X 105 9.47 X 105 58,000 9.25 X 105 " " ~;2,000 7.57 X 105 " ~' 190,000 p2BHs - p2BHF 8.37 X 105 ~ "' 110,000 9.06 X 105 " '" 41,000 ABSOLUTE OP~ FLOW = 9.47 X 105 ~' 0 = 9.,47 X 105 Q 1397 336 5032 2977 1141 C z/8 6.25 1/2 112.72 1/2 112.72 1/4 26.51 G=. 575 Z=I P CP T GT ~ GT 89'7 23'779.47 504 289.800 17.02 915 5718.75 505 290.375 17.04 762 85892.64 507 291. 525 17.07 441 49709.52 485 278.875 16.'70 727 19272.77 496 285.200 1.6.89 1397 336 5032 2977 1141 6- 5 N=.813 10 9 8 7 N ICOLAI CREEK OPEN FLOW POTENTIAL T E ST - July 6, 1967 CSG PRESS USED I0 8 7 6 5 u 10 ¢ 8 i'- I 1 ~ 6 7 8 ~30 2 Q - MCF D REcEiVED' JUL 2',~.1967 4 5 6 4 5 6 7 8 910 Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 orr,~E Anchorage NuMBE. ANO 34161 ~icolai C~ee~ LESSEE'S MONTHLY REPORT OF OPERATIONS State Alaska Borough Kenai Field Wildcat TAe followir~ is a correo~ repor~ of opera~ior~s arid prod~o~ior~ (ir~ol~dir~ drillir~ and prod~cir~ w,~8) fo~ ~ ,,,o,~t~ of ........... ?___u_.n__?_ ...................... ~9__._6__7, ............................................................................ .~,,,~' ~ ~aa~ee~ ....... ~_:___9--:__--~-°--x-----§-e---4-- ............................ Co,~p~,~y _:___~.-e--x_--a--.¢_o-~c.---~/* ....... : ........ Anchorage, Alaska 99501 $i~ed___~_':~~ ....... ................ -~-79-:-~-~-~ ......................... ' ................................ ~,, ~.~, ....... ~__C_~__9___~.o. ~.~..m_~_.~. ................ Ph~or~e ................................................................................... ~EC. AND NICOLAI CR] Twp.. I RAN6 WELL DAYS Paov~cmv WEL Nell BARRELS OF OIL shut in ~R .~tt i: Cu. F~. oF GAS (In' thousands) ce month. ~ALLONS OF (]ASOLINE RECOVERED BARRELS OF Wa~,~a (If none, so state) REMARKS (If drillinf, depth; if shut down, oauoe; date and result of test for ~a~oline content of ~) RECEIVED JUL 5 ,1961 >iVI$1ON O~ MINES & MINEEAL~ ANCHORAGE NOTE.~There were ................. rko. ........................ runs or sales 6f oil; ...... no ........ M cu. ft. of gas sold; no runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. TEXACO PETROLEUM PRODUCTS June 7, 1967 P. 0. BOX 664 ANCHORAGE, ALASKA 99501 Mr. Thomas R. Marshall, Jr. Petroleum Supervisor State of Alaska Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Marshall: Enclosed please find the following logs for Texaco's Nicolai Creek ~3 Well located in Section 20, Township 11 North, Range 12 West, Seward Meridian: . .1 sepia and 1 print of Induction - Electrical Log for depths 2001-6895'. .. 1 sepia and 1 print of Dual Induction - Laterlog for depths 6300-8823'. · .1 sepia and 1 print of Mud Log for depths 600-7390'. . .1 sepia and 1 print of Mud Log for depths 6895-8841'. Very truly yours, Claude H. B~ District Landman CHB-khb enc. RECEIVI D jun 8 1967 DIVISION OF MINES & MINERALS ANCHORAGE ~7 ..... SUBMIT IN DUPLI/. · !~T '4 ~' Si~ATE OF ALASKA (See othe7 tn; structions on OIL AND GAS CONSERVATION COMMISSION reverse side) WELL COMPLETION OR RECOMPLETION~ I~PORT AND LOG * TYPE. la. OF_.~VELL: b. TYPE OF COMPLE~ON: 0 OVER EN ~ESVR. ~her ~ WELL 2. N~ME OF OPERATOR ~] Texaco Inc. ADDRESS OF OPERATOR 4. LOCATION OF WELL (Report location clea ~a ' ; ~ , i ~ ' 'qu i ) Atsu~ace 1668'E and 3369.'~ of S~c~r 8ec.20~ At top prod. interval reported below Straight ff6~ ~ At total dep~ ~ [ 14. PEE~ (~0. ~': D~E ISSUED ..................................... I ........ 15. Vi~ sPU~E~"]-'i6. DAT~ T.D.' igiCHgb'-l"lT'. DAT~"~6'MPL'.'(Read~ t0 3/19/67'1' 4/28/67'l May 4, 1967 Effective: July 1, 1964 ~.~., 5..LEASE:DESIaNATION AND ~ ~0[ ~,' USL AN034161 '~" ,.. 6. IF INDIAN, ALLOTTEE OR TRIBE NAb~ 7. UNIT AGREEMENT NAME Nicolai Creek S. FARM 0R- LEASE NAME 9. ~ELL NO. Unit 10. FIELD AND POOL, OR WILDCAT 'Wildcat i'l. 'SEC,, T., R., M;, OB BLOCIC'~*ND S~RVE¥ OR AREA ': ' Sec. 20 TllN-R12w . _ 12. BOROU(~H ['18. STATE. Kenai [. AlaSka 18. ELEVATIONS (DF, RKB, RT, GR, ETC.)* I 19. ELEV. CASINGHEAD -+' 200' GR '[ ~% 20. TOTAL DEI~H, MD & TVD 21. PLUG, BACK T.D., MD & TVI) 22. IF MULTI?LE COMPL., '~ I I HOW M~* - 8841 I .2522 ' To 1900, Btm 2380 ~: ~fi~ [~ ,-.. - TYPE ELECTRIC AND OTHER LOGS RUN DIL, IES, BSC, ~, SWS, GR 23. INTERVALS ROTARY ~0OLS - DRILLED BY . > ] -:All All MD CABLE TOOLS I · ~5. WAS DIREcTioNAL SURVEY MADE IOn ~iPmete= 27. Wis 28. CASING RECORD (~eV~t all z$ri.~s ~ ~ well) · .. . OASINO SIZE WEIGHT, LB./FT. DEPTH SET t~D) [ HO~E. SIZE CEMENTZN~ RE~OBD i~OUN~ 20" 85,01 282 ~g. ;~ ~ ?20sx - Good-Returns i3 3/8" 54.5 o ~f, !~J ~ 1770 sx-Good RetUrns - , ~' :' ...... ~ ~i~~l ~:'; .. 29, LINER RECORD :'% ?: ~ ~'] l.~ 30. TUBING RECORD ~ 1~41 2522 220 c: , --~' 2 7/8 ~008 .... m' [2 !~:' C} a2. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, 31. P~a~oRATION a~coa~ (f~ervat, size and n~b~~) CD , , ~.. . 2005~2.0.) 2-~"'holes-pe~'-'ft,- ........ None ' ' 2201-38) 2360-80) is 2302-28) ~ ~.* P~ODUCTION · s/3/ 7 ..... as'- e ..... 940p i9 ~" -- 725- s -- . ~ -- ~<, 1.5-, c -- vented TEST WITNESSED BY . Wunn icke0 K. Vond~~ ~ 35. LI~T OF ATTACHMENTS ~... Logs sent separate cover '"_ 36. I hereby certify that the foregoing and attached information is comIff~te and correct as 'determined from all available records S~GNED TITLE *(See Instructions and S~ces [or ~dditional Data On Reverse Side)- DIVISION OF MINE,~ & MINIf. IIAL~ INSTRUCTIONS · or b~l~l~ pursuant tx)applicable Federal and/or St. at(? t:i~s aq(l regulations..Any n.~cessa~, ~[)~'at ~nstl~s ~~.~,~.~ ..... a~, b~ obliged from the Ioc~ Federal ' *-~,hm;~ed narticularlv with rezard to local area or regional proc~ures an(l practices, e~tner are snow~, o~,u, u~ ,,-, ow.,oou~ o~,. ~, ~ ~ ~ , :-,,and~ff"S[a[e office .... See instructions.on ~tems 22 and 24, and 33, below regarding separate xeports for separate complettons. .ff~f n~:'flled prior 'to. the time this summary r~,{)rd is submitted, copi6s of all currently available logs (drillers, geologists, sample and e0re analysis, all types e!eetric, etc.)~ forma- tio~:~.~ pressure [es[s, and direcSional surveys, sh()uht be attached· hereto to the extent required by aI)pJicabh~ Federal and/or S~te laws and regulations. All attachments ~hould be listed Ga-this form, see item :15. /~$~m~4:: I~ there are no applicable Stare r~uircmen[s, locations on Federal or Indian land should be (les('.rib~t in accordance with Federal r~uirements...Consult local State ::::~r Federal office for specific instructions. ' 15~ffi~'8: In(tica[e which elevation is used as reference [where not otherwi~ shown), for depth measurements given in other spa('es on this form and in any attachments. ISg~ ~d 24: I~'this well is completed for separate production from more than:6n~ interval zone (multiple completion)~ so state in item 22, an~' in i~m 24 show the prQducing , s. . ~ · interval, or mterv~!s, top(s), bottom(s) and name(s) (if any) for..only the interya~"re~ ~ item ~. Submit a ~parate repo~ (page) on thin form, ad~uately identified, for each additional interval to be separately produced, showing th¢:additional data pertinent to such interval. I$~m 2?: "Sacks Cement": Attach~ supplemental records for this well shoffid show the derails of any multiple stage cementing and the location of the cementing tool. -" I$~m ]~: Submit a.~parate completion report on ~is form for each:interval to be seParately produc~. S~ instruction for items 22 and 24 a~ve.) 37. SUMM.~R¥ OF POROUS ZONES: -'i ': SHO~ AI,I, IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED 'INTERVALS'~,i A3VD ALL DRILL-STEM TESTS, INCLU~DING 38. GEOLOGIC MARKERS · i., DEPTH INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN, FLOWING AND SHUT-IN PRESSURES, AND RECOVERIES /..~ ~ TOP .-"FORMATION - TOP J BOTTOM DESCRIPTION, CONTENTS, ETC. · -' NAblE "' , , ~ '. : ' · MEAS. DEPTH TRUE YERT. DEPTH ,_ ~dl'e Kenai , 2201 2380 Tested with conventional Tester All Middle'algal Lower l,enai At tnt-Ervals Flowed dry gas as follows No clear cut depth of top Lower Kenai .. · Choke PSIG MCFP,,,R .. :'- 7/16 725psig 3560 ~ ,,.: , 3/8 820 2940 ,,.. 5/16 915- - - .2300 .. 1/4 ~.' 940 1450 · · .. · : · · , . -~ ,, .; --. ... __ Midd Granite ]Point, Alaska licola£ Czeek Unit 1668' Eant and 3369' $outJ~ o£ Hortheast cornex of Section 20. May 31, 1967 Fiel~ FozeMan i=ch 19, 1967 20' S~£. ~ 282 - ~e~t~ sol~ w/720 sx 13 3/8" Suxf. to 2001- ~~ted sol£~ w/1770 sx 1941-2522' ce~n~ed w/220 sx holes per £OOt as £oll~sl 1900-1930, 2005-2020~ 2201-2238. 2,302-2328, 2360-23~E C jUN let ion Report Cree.~.~ Un (Note: Days ru~ 8:,L)J A.£,~. to 8:00 A.~i.) Spudded at 2:00 ~.M. March 19 1967 14ud 84~, vis 82s~c. Drilled 17'$'~ hole to 285', Drilled ahead to 300' OpeneO hole to 26" ~o 30~)' Ran 282' 85.01~ I~ and cemented through Duplex colla~ with 770 returns. Insta.iled 20" casing head and BOP~ -. 20" 209~, Single .,~.3ate and 2000 psi Hydril. Drilled 12~" hole to 200~'. Razz X~S and BCS. ~tud weight vis 50 sec. Opened hole to 17;~,i'''. Mud weight 88% vis 50 sec. Ran 48 jt~... !3 3/8"~. ; 54.. .~ J-55 easing and. ce~:aented throagh shoe at 2001~ with 1770 sx neat cement. G~d surface returns., Dropped away last ~ 100 cfr. ft, displacement. C I ,p 5~30 P.~t. $~ood ce~ente~ ~til 12 ~tidnight. Checked 20" X 13 7/8" annulus for 9as slight bubbling. Tore out BOP~ set csg slips. Installing' BOPS. installed 12" $-900 Double Gate and t2" S-900 Hydril. up 20" X 13 3/8" annulus wi=h 2000 psi by mistake, 13 3/8" casing. Pressure~ Collapsefl ~£colai Creek UnlL %~,~;, Sec. 20, T. Ii ~.~ R. 1i ¥~..., ~.M. ~r_ch 2_9. 1967: .... :._. 1.11,~ Backed out to~ 3o~nu of i3 3,/8'~ casin,~ Sc~c~ea in ne~~ ~op j ~"~" 38~ below KB. Re-~saalled slips anO pacKin9. Installed Test casing Lo 2000 ps;t -- ~. Located ~op cement h~ annulus at Drilling ahead with 9 ~ 'to 79~, vi~ 46 at 3S25'. D,~'ille~ 9 7/8" hole tO 7392', ~u~ ~, 76~:, vis 43 sec. $:~uck pi~ a~ 7387~ :~ki~ a connection ~ ..... ~" with sko~. f~ee a~d g~ ~:~ud lube. Working stuck pip~. Un~le '~o circulate at 3500 psi. Unable 'to ~ve pipe~ 'Ran free point - f~ee '=o -top stabilizer -~0~ off bottom. At~e~pt,ed to back off 9 collar~ f{.~n. No goo~. Backed sub and bit. ~ ':"~' ', ~ . Dyna ~ itl and ~'~ :~ weight '75~i~', Drilled ahead in 9 7/8~ l~oie '~o 816,8, Con~i~erable '~roub!e '~i~t~:~"~ slou~hin~ c~at ~tick~g bit. Dzillin9 ahe~f~, only 2' and pick, in9 up behind after .~ 'h:.~'s, ~ud 7~ u,is 46. ,:~ ~ ~ ' ~, ~, ~ out BOP~ installS, t~ing head~ reinstalled BOPS. Change pipe Nz~ol.,a]. C~eek Unit Sec. 20, T. Il N., R.12 U., $~. ra:'~ testel set at 1986' di~ not hoi,O~ R~se'h at ~',*:,~ not hold. P.O. ~angeC; over uo water would not fl~, Make up tester~ 7/16 725 psi9 3/8 820 294~3 ~/16 915 1/4 940 1909-1939. Ran out $Oi~, Installed tree, Dntoaded well and shut relea~e~ 12~01 A..~, 5-5-'67° w~ll. shut Willis Flow ,~eaus as !nstalle~ Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 o~,:E Anchorage DR UNIT NA~E LESSEE'S MONTHLY REPORT OF OPERATIONS State ....... Ala__ska .................... Boro uvh ........ Ke/n_a__i .................... Field ........ _Wild. ca_t ................................................ Tl~e followin~ is a correo~ repor~ of operations and prodz, ction (incl~clln~ drillin~ a~,d prod~cin~ wells) for the month of ....... _M_ja__y_ ............................ 19__6._7__, _ ........................................................................... ~l'e~t's addressr. O. Box 664 Company ....... ~-~~ ........... e An b-[ ....................... ........... ..... - ........... Cu. F~. o~ GAs S~c. ~ B~R~LS O~ On. (In thousands) ~4o~ ~4 5/1 at 2517 weight ) at 193 oe at 2 ~ed 10sx . Ran ' P ran . ul~ , 5/2 1935' 1' · Line: Lin ~hed d( ' during cl. plug at '. Teste~ tubing reinsta] 2 7 llar ig lubr 5/3 Per . 22 tes , did Res~ p. to not f2 5/4 Mak .ran, 160. Tet Tes Sta 190 5/5 Tot 1~0 4r. Bill ?ulled t~ :ubing :alled Well psig Um OALLONS OF OASOI/NE i~ECOYERED ran Sck · oaded of pi! 17 ' . C~ 6 1/8" .2%" bi~ t°p a~ ceraentJ t casin¢ .led BOi .cator. 1-38. t at ,ted to WA'~Eg (If none, so state) ,e. Raz ~mented bit to top c 1941 ' ng. to 70( E. Ch~ Teste( 302-28 '69 ' - atmosP 2~ 1, · O. S., ~ [nd Mr. P ~mberg~:r shot ~ell ar,d shut RE~IARKS (If drilling, depth; if ohut down, oauoe: date and rmult of teot for Sa~oline eantent of f~t) 14 Jts., 7", with 220 sx neat hard ment 1935'. shoe ~22 '. [n 6 1/8" bit ipsc - OK. Tore rage pipe rams to BOPE and tubing 2360-80, ran ga in did not ho id. .ere as follows: ,60MCFPD '4Q ............. ;00 .H. Vonde~," 2-½" holes/ft · in. Rig released NOTE.--There were ............... ..~...O. .......................... runs or sales of oil; ....................................... .rio.... M cu. ft. of gas sold; n..0. ....................................................... runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the §th of the succeeding m,~trT ['VI:I) directed. DIVISION OF MINES -Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 L.No or~,~ Anchorage L~A~ NUM.~, ANO 34161 LEASE nl~ UNIT NAME Nicolai C~eek LESSEE'S MONTHLY REPORT OF OPERATIONS Tl~e followinff is a eorreot report of operatior~s and production (ineludin~ drillir~ff and prodt~ein~ wells) for the montl, of ____~P_~_i~_ ........................... , 19__6_7, _ ........................................................................... .4~er~ffs address ..... ]?_ .... _O -'- __ Jio_X__ _6 6.~ .............................. Company ........ ~I1l~{~_O__~n.o..:. ............................ ............ _A__ _n_ _c_ _ _13 9_ _r_ _a_ 9_ _e_ :_ _ _ ~ _A_ _l_ _a_ _ _s_ _k_ _a_ _ ........................................ Si~ned_~.~~J, S. arbe BE0. AND B&RREI.8 OF OIL ORAl?ITY OABOLINE WATER (If (If drtllinz, depth; if shut down. osuael ~ OF ~ TWP. RANGE WELL DAYs CU. FT. oF GAS GALLONS or BARRELS OF REMARKS NO. Paom~c,, (In thousands) d~t~ and result o! te~t ~or ~amolia® - R~rCOVER~D none, so state) NICOLAI CIREE~ U~IT ~3 4/1 - 4/~.1 Drilled 9 "/8" hole to '~392' 4/12 Stuck pipe at 7387' mak ~ng a c(~nnecti()n - spotted oi 4/12 - 4/'14 Fishing 4/15 Laid cement- plug, top 6!)00', l~.~a~ing [0-7 3/4" D.C. I in the hol(,~. Ran IES a~d BCS. 4/16 - 4/'28 Drilled ah(.~ad in 9 7/8" 'hole t¢) 8841' TD. 4/29 Ran logs. 4/30 Laid 50 sxl cement plugs at 720() and 5{)00. Laid 100 plug 2656 :o 2480'. .......... -~_ lo sx NOTE.--There were ...... no ................................... runs or sales of oil; .........n...O. .................................. M cu. ft. of gas sold; ..................... rL.o. ................................. runs or sales of gasoline during the month. (Write "no" where applicable.) : 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 Division of Mines & Minerals by the §th of the succeeding moa[J), [~n~ss~ot~[~vi[~ directed. I,iAY 10.1967 DIVI,StON OF MINES & MINERAL~ ANCHORAGE FORM SA - I B M E.MORANDUM' TO: J-- Thomas R. Marshall, Jr.(~ State-of Alaska DIVISION OF MII~S AND MII~RALS DATE : J~y 4, 1967 FROM: Karl L. VonderAhe SUBJECT: Field Trip to Texaco, Nicolai Creek 4~3 ~ Texaco, Inc., Operator CONFIDENTIAL Left office at 4:30 p.m., May 3, 1967, picked up Bill Wunnicke of USGS and drove to airport. Flew by Sea Airmotive helicopter to Texaco's Nickoai Creek ~3, arriving there at 6:37 p.m. The well vas on test and the gas was being flared. It had been flowing since 1:17 p.m. and was not shut in until 8:15 p,m, Obtained all required information and started back by helicopter at 7:21 a.m., May 4, 1967. Very foggy and had to sit down on the east bank of the Little Susitna for an hour waiting for fog to clear. Finally took off at 9~24 a.m. and came on to Anchorage. In crossing KnikArm to Point Woronzoff observed that most of the Arm was covered with rainbow colors as of light oil on the water. Probably oil lost from the tanker which had run aground recently and damaged at least one compartment. Drove home, dropping Wunntcke off on the way and returned to the office at 10:45 a.m., May 4, 1967. ~tV/cw CONFIDENTIAL Test of Gas Flow:~ on Texaco, Inc., Nicolai Creek #3 May 4, 1967 T. D. 8841' Plugged to 2522' 13-3/8" cmtd. at 2001' 7" line~ cmtd. 2522'-1941' Perf. 2 holes per;!ft. 2201'-2238'; 2302'-2328'; 2360'-2380' ,,.,May 3, 1.967 DST - Set packer 2160', Tail to 2173'. Opened tester 1:17 p.m. on 5/8" bean. Rates of 3 to 5 million cf while cleaning up. 4:55 p.m. opened on 7/16" bean 5:02 p.m.T.P. 750 psi Gas temp. 58° 5:12 p.m. 740 psi 60° 5:22 p.m. 722 psi 60° 5: 32 p.m. 720 psi 60° 5:42 p.m. 710 p~i 60° 5:47 p.m. 710 psi 60° 5:57 p.m. 710 psi 60° 6:03 p.m. changed to 3/8" bean 6:13 p.m. 840 60° 6:23 p.m. 820 60° 6:33 p.m. 820 60° 6:43 p.m. 810 60° 6:53 p.m. 805 60° 7:03 p.m. 805 58° 7:05 p~. changed to 5/16" bean 7:10 p,m. 880 7:20 p.m. 900 7:33 p.m. 900 7:38 p.m. changed to 1/4" bean 7:40 p.m. 930 7:50 p.m. 930 8:00 p.m. 940 8:15 p.m. shut in for B.H.P. 58" 56° 56° 56° 52° 50o Pressure charts - Bottom hole. I H.P. 1076 psi I F.P. 392 psi I $.I.P. 1047psi F. H. P. 1076 psi F. F. P. 988 (1/4" bean) F. S. I.P. 1047 psi F,,%ow,,,,Test,,- Ca!,cu~!ated rate of flow 7/16" 725 psi @ 60" = 7,2.5,,x 85.,13, = 3567 MCFD 17.3 3/8" 820 psi @ 60° = 820 ,X, 6,1,2,1,, = 2901 MCFD 17.3 5/16" 915 psi @ 60° 9!5 x 43.,64 = 2308 MCFD 17.3 1/4" 947 psi @ 60° -- 94? × 26.51 -- 1451 MCFD 17.3 Pulled out. Considerable gas working through the mud. Ran in with Schlumberger gun and perforated 1900'-1930' 2 holes per foot. Ran tubing and rigged up Christmas tree. Well ready to put on production. Test witnessed by Wm. Wunnicke for USGS ar~ Karl L. VonderAhe for Division of Mines and Minerals. KLV/cw 7/0 bo .~ , ~ 7/o-- bo ~0 ~O bo /7/o ', l~y ~ ~967 1~: ~,, N~colai Creek Unt~ #3 Texaco ][nc.T 0perar~r l~r. J. S. ILaebez Taxaco P. O. Box 661 Anchorage, Alaska 99501 Dear ~lr. Barber.' Attached is your approved cot~ of the Sund~y .qoCice (~--3) on the above captioned well. Very truly yours, Karl L. VonderAhe Petroleum Engineer Enclosure Form 9-331 (May 1963) SUBMIT IN TRII-.. JATE* U fED STATES DEPARTMENT Of THE INTERIOR ,(Otherverse side)instructi°ns on re- GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) WELL WELL 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR' 4. LOCATZO~ OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 14. PERMIT NO. 1668'~ ~d .3369'H e£ ~ ~er o£ ~. 20 Form approved. Budget Bureau No. 42-R1424F 6. IF INDIAN, ALI, OT;~EE OR TBIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR' LEASE NAME 9. WELL" NO. 10. FIEIJD AND POOL~ OR WILDCAT 11. snC.~ T., ~., M., OR BLE. AND S~R~ OB sec.~O 15. ELEVATIONS (Show whether DF, RT, GR, et~.) 16. Check Appropriate Box TO Indicate .Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT ~E COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF': FRACTURE TREATMENT ALTERIN0 CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.: Report results o~ multiple-completion on .Well Completion or Recompleflon Report and Log'form.) 17. DESCRIBE PROPOSED OR C~)MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including.e~tmated date of starting any proposed work. If well is direetionally drilled, give subsurface locations and measured and true vertical'depths for .all markers and zones perti- nent to this work.) * ~ 2522' LaitY: 50 ~ plug w/~ a~ 73~' ~ 5002' ~ ~ ~ plug w/~ at ~~" ~ a~ ~~~ 7" ~ ~Op X941'~~ 2522' 20~:- 2020 2201 - 2360- 2390 18. I hereby certV~:~and correct SIGNED TITLE (This sp~for ~e~er~,~;e~c; U~e) .~ ~ APPROVED BY ~/ ~ ~ TITLE CONDITIONS O~ APPROVe, IF A~: DATE R E C El V EO *See Instructions on Reverse Side i,~AY 1.1967 DtVI~ION OF MINES & MINERAt~ FOrm 9-331 (May 1963) STATES S~BM~T DEPARTMENT OF THE INTERIOR (Other instr.ctio.., on re- verse stde) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL wELL ~--~ GAS WELL [] OTHEE Wfldc&t 2. NAME OF OPERATOR 3. ADDRm.~_S OF OPERATOR ~. O. B°x 664 - ~chor~e, &laska 99501 4. LOCATION OF ~'ELL (Report location clearly and in accordance with any State requirementS.* See also space 17 below.) ~ At surface 1668' B .and 3369' N o£ ~ ,-corner of Sec. 20 14. PERMIT NO. 15. ELEVATIONS (Show whether DP, RT, eR, etc.) Form approved, _ Budget Bureau No, 42-R1424. ,.,~ 5. LEASE DESIGNATION AND SERIAL NO. /~ USL ~11034161 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME $. FAR~OR I~EASE NAME - 9. WELL~ NO. 10. FIELD AND POOL~ OR~ WILDOAT #ildeaC 11. SAC., T,, lt,, M., OR Sr;Z. AND~ SURVEy, OR'~EA ' ' se.;~O TilH'ItI2w 12. C0U~T~ 0R PAR!SHJ 16. Checic Appropriate. Box T° Indicate .Nature o~ Notice, Report, or Other DataI - NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE . SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRIN0 WELL FRACTURE TREATMENT ALTERIN~ CA~ING SHOOTING OR ACIDIZING ' ~BANDoNMENT* (Other)' (Other) (NOTE: Report resultS of multiple eompletign onWeH Completion or Recomliletion Report aiid Log;.form.) . 17. ~ESCRIEE I'ROPOSE9 OR C~)MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including.e${i~ated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical .depths~for all markers and zones pertl- nent to this work.) * We ~ propose to ~ill ~ead to 9200' (Or£gi~l program was to ~ at -+ 8200') (This sp~ce for' F~de~-M: ox)%t~-~f~ use)~ CONDITIONS 01~' XPPROVAL, IP A~: TITLE 4-24'67 DATE DATE . . *See Instructions on Reverse Side Form No. · STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LANo .~r,=~ Anchorage L~^.~ .uM~. AN034161 LEASE DR UNIT NAME Nicolai Creek LESSEE'S MONTHLY REPORT OF OPERATIONS TAe [ollowi~ is a eorreot report of operations and produetio~ (i~eludi~ drilli~ a~d prod~ei~ wells) for the month of .~_::~9.1:C3a ......................... 19___6~, ............................................................................ ,4~ent's address .................................................... P, O. Box 664 , .............. Compar~y~_~.__~_~_..~.~~....~_.~:~.._.......~TEX~CO Inc .............................. ~_c__?__~_~.e._:_b_.x___a__~_a____.?2_~9_~ ....... s~.a ~o~e ................... _ _2_ 7__ _9_ _-_ __~__4__s__ _q ....................... ' ..................... ~e,,t's ~i~e .... _r___i__e_kd__~ .................... SEC. AND BARRELS OF OIL GRAVITY (~ASOLINE WATER (If (If drllltnz, depth; if shut down, oausel 14 Or ~ TwP. RANOE WELL D~s. Cu. FT. Or GAS GALLONS Or BARRELS Or RElYIARKS NO. P~o~oo,~ (In'thousands) dat~ and result of test for gasolia~ · RECOVERED none, so state) ooatea~ of sa~) . , · Spu,~t Mm:ch 19, 1967 tit 2:00 r.M - ,ri' od ho , : an 20" casing and cemented thr, DUgh ~he shoe' at !82' with 720 sacks neat cement. '22. 3/2~ Drilled 12% hole to 008'. Ran electric lo~s '25 - 3/25 Ope~%ed '~2¼" hole to .7%" to 2008'. · '27 Ran 13 2~/8" casing a~d cemented through the shoe at 2001,~ w~.th ~1770 sack:; neat cement. 3ood surface returns. '28 - 3/29 Ins:all~d and tested 12"-900 BOPE (dguble g~te and Hydril) '30 - 3/31 Drilled 9 7/8" h~le ~o 3860' ...... , .... 3/2 3/2 NOTE.--There were ............... no ........................... runs or sales of oil' . ........... I1.O. ............................. M cu. ft. of gas sold; ............. ~.O.. ........................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE--Report on this form is required for each calendar month, regardless of the status 'of operations, and must succeeding mo , es o ' e be filed in duplicate with the Division of Mines & Minerals by the 6th of the ,,n~,..~.Fn~t. ~ ~h~ directed. APR 7,1967 D DIVISION OF MINES & MINEI~ ANCHORAGE Form P--3 - , STA[ ~F ALASKA SURMXT IN TRIP] · : ~ · (Other instructions OIL AND"GAS CONSERVATION COMMISSI'ON verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for Proposals to drill oT to deepen or plug back to a different reservoir. U~e "APPLICATION FOR PERMIT~" for such proposals.) Effective: July 1, 1964 5. LEAS~ DEfI/GN&~ION AND IIEBIAL NO, USL ANO 34161 - 6. IF INDIAN~, ALLOTTEE OR TRIBE NAME OIL ~--] GA8 WELL WELL OTHER 2. NAME OF OPERATOR 8. FARM OR Y.,~'_ABE N.A. MR' TEXACO Inc. USL 8. ADDRESS O~ 0~EBA~OB ....... 9. W~L~ NO, · P. O. Box 664, Anchoraqe, Alaska unit. ~3 4. LOCATZON Or WELL (Report locatiOn clekrly and in ~cc0rdance With' any' State reqUirements.* See alsO space 17 below.) ' '~ At Surfsee 1668'E and 3369'N of SW'corner Sec. 20 14. PEnMZT NO. 15. ELEVAT~9-N.B (Sho~ whether DF,-BT, OS, ere.) 67-7 ± 200' KB UNIT AGREEMENT NAME N i¢ola~i Creek Check Apl~ropriate Box. TO Indicate .Nature of Notice, Report, or Other D~ NO~ZCE OF X~TEN~ZO~T ~o: BUBS~U~T n~P,m, w~ I, I e~,~e~ ~,~$ I I (Other)' 'Other' I~-I (No~: Report ~esult~ of m~t!~e2.~mDle~o~ on .WeB ~ ~ · ~ - ' Completion or Re~ompmtion ~ff~ ~Lp~ ~o~m~) . 17. ~,s~am, PaO~S~D os C0~BD 0~aA~o~s (Cleanly'state ~lfPertinent details, and ~ive pertinent dates, ln,ludtn~[~ti~ted 9ro~osed'wer~ !f well Is dl~tton~ d211~, i!ve ~ub~ l~tlons ~nd meamired and 'true vertical depths nent m ~ts ~rk.) · Subject ~ell ~as spudded a2 2:':~00 P.~. ~a~ch 19, 1967,~ TITLE ~i~l.'d ~or~man APPROVED BY CONDITIONS OF APPROVAL, IF.ANY: TITLE *See !nmu~!on. on Reverse Side TEXACO I ~C. PETROLEUM PRODUCTS P. O. Box 664 Anchorage, Alaska 99501 March 1, 1967 Mr. Thomas R. Marshall, Jr. State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Marshall: Re: Nicolai Creek Unit 453 Well Texaco Inc., Operator Please refer to our Permit 4567-7 for the drilling of Nicolai Creek Unit 453 Well in Section 20, TllN-R12W., S.M. We wish to advise that it has become necessary to revise the location shown under item 4 of the Permit to the following. - 3369' N and 166B' 'E from the iSW corner of Section 20, TllN-R12W., S.M. New plats are presently being printed and will be furnished you within a few days. Yours very truly, TEXACO Inc. ~ Claude H. Brown District Landman REC IV D I IAR 2 1967 DIVISIOIN OF MINES & MINERA~.~ ANCHORAGE 1967 ~exaco, Inc., ~eri~or AUc~~ ~ F~~ 7, 1967. 1 12 I I I I ! t t i I ? I 8 ~ 9 I 10 I ~ I ._i t3 24 1 I ! 1 I I I -t 1 1 14 I I I I I I 25 1 t ~ 25 30 t . t ~ J 31 I J I 29 28 J I 33 i i 26 "SCALE' 1": 1MILE CERTI'F ICATE OF SURVEYOR I hereby certify that I am properly Tegist&red and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct, I I ~TII N 'r / FEB 1 ,1967 SURVEYO. RS NOTE DIVISION OF MINES & of U~S.C.~ G.S. Tr~ang, ulation Station "Goose Flat" and control point "F.M.L. No. IO" Electro-Tape diat~ce and bearing was measured from "Goose Flat" and cheered by shat-gun flares from "F.M.L. No. I0" -.. I$1 Lecat ion Survey of NIKOLAI CREEK LecJted i n Surveyed for TEXACO INC. 5 th Ave. No. ~3 F.M. LINDSEY & ASSOC~ LAND 8, HYDIIOGRAPHtC SURVEYORS f.O Box 4'081 A c t J~l Aec FORM SA-I B 100M 9J65 MEMORANDUM TO: F- State' of Alaska DIV~$ZOII O~ ~ AI~ ~ FROM: DATE : SUBJECT: Fmclosed a~e the ~pp~ application for permi~ ~o drill (and work order), a letter with Fish end Came stipala~ioel, ~d ached ia the mmmt of flEty dol- lars ($50) £or fili~ T~I/Jmd Eric los~rres ~coI~ ~reek Unit Texaco, Iuc., ~erator ~r. D. L. _- WALTE~ '."' :: DEP~TMENT OF:FISH' ' / DiV. of Co=m . '. ' .' ' ' :i'1018 INTERNATIONAL AIRPORT ROAD - ' . / ANCHORAGE 99502 · February 3, 1967 Mr. Thomas R. Marshall, Jr. Petroleum Supervisor Division of Mines and Minerals 3001 Procuptne Drive Anchorage, Alaska Dear Mr. Marshal'l: This-is in reference to your Memorandum of January 26, 1967, concerning Nicolai UniC Well ~3. The Depart~enC of Fish and Game requests Che following wildlife sCiPula2ions be incorporaced in che permit Co drill: (1) (3) Prior co drilling, che operator musC construcC a sump of SufficienC size to conCain all ~rasce well fluids. Prior to drilling, Che operaCor must conscrucC a ring dike around Che drilling area to conCain any spills cha= mighC occur. Upon compleCion or abandonmenC of che well,.Che sump musC be cleaned of Oil and filled in. Yours truly, /--'"~ x:? ...:, ,,,'~ Paul A. LeRoux I~a cer Projects PAL:eh CC: ., . Meacham Huizer Rearden CroxCon SCefanich ,:' R'EC fiVt:g' FEB 6,i~61 Paul ~ 3ammry 2~ 1967 LAND DEPARTMENT DOMESTIC PRODUCING (WEST) TEXACO PETROLEUM PRODUCTS January 19, 1967 8850 WILSHIRE BOULEVARD LO8 ANGELES, CALIF. 90005 NICOLAI UNIT WELL NICOLAI CREEK AREA~ ALASKA Mr. Thomas Marshall, Jr. State of Alaska Dept. of Natural Resources Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Enclosed herewith is Application for Permit to Drill the above subject well, in triplicate, together with our check in the amount of ~50.00. The actual spud date is tentative as the availability of rigs in this area is scarce. Yours very truly, TEXACO Inc. " R~molds ....... JPR:EVB Encls. cc: Mr. W. J. Linton U.S. Geological Survey P. O. Box 259 Anchorage, Alaska ANCH C) ~AC; ~: STATE OF ALASKA Effective: July 1, 19~ (Other Instructions on reverse side) OIL AND GAS CONSERVATION COMMISSION la. DRILL b. TYPE OF WELL 2. NAME OF OPERATOR TEXACO Inc. APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK TYPE OF WORK DEEPEN [] Exploratoz-yZ0NES'NGLE PLUG BACK MULTIPLE ZONE 3. ADDRESS OF OPERATOR 3350 Wi. lshire Blvd., Los Angeles, Calif. 90005 4. LOCATION OF WELL (Report location clearly and in accordance with any State re~luirements.*) At surface 31140' N. & 1500' E. from 8W/co~ner See.20,TllN.-R.12-W. At proposed prod. zone ,Same 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approx. 11 miles West of Tyonek Village 1~. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE LOCATION TO NEAREST PROPERT~ OR L~A.s. L,NE, FT. 1500' 2260 (Also to nearest drlg. unit line, if any ~. DISTANCE FROM PROPOSED LOCATION* 19. PROPOSED DEPTH OR APPLIED FOR, ON THIS LEASE, FT. uLEASE D~IGNATION AND SERIAL NO. .S. l~ease g.~ IN~N~ ~L~0'~TEE OR TRIBE NAME 7. UNIT AGREEMENT I%'AME Prop.Nicolai Creek Unit ~. FARM OR LEASE NAME U.S .Lease 9. WELL NO. Nlcolal Creek Unit 10. FIELD ANr~ POOL, OR WILE~CAT Wildcat 11. SEC., T, R., M., OR BLK. AND SURVEY OR AREA Sec. 20,TllN-RI~W, 12. B.OROUGH SH[ 13. STATE SM Kenai Alaska 17. NO, OF ACRES ASSIGNED TO THIS WELL 6t40 20. ROTARY 'OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GE, etc.) 22, APPROX. DATE WORK WIt~L START* ~00' K.B. ~ June 1967' 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SETTING DEPTH QUANTITY OF CEMENT SIZE OFCASING [ WEIGHT PER FOOT ! 'SEE ATTACHEDJ 6 ~ in amount of $100,000.00 Statewide 0il and Gas BordNo. B-l?, January 18, 19 ~ IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dtrectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. 24. I hereby cg 'fy that the Foregoing is True and c(~rrect. (This space for Federal or State office use) PERMIT N0. ~ 7 --7 CONDITIONS 0F APPROVAL, IR ANY; APPROVAL DATE THOMAS R. MARSHALL, JR. Executive ,Secretary TITLE DATE Alaska Oil & Conservation Committe~ *See Instructions On Reverse Side LA-425 WORK ORDER DATE: December 20, 1966 ~LL: Nicolai Creek Unit 53 FIELD: Wildcat AREA: Granite Point, Alaska RE~. ELEV.: K.B. 200'+ PERSONAL AND CONFIDENTIAL EST. NO.: 7636 PROPOSED T.D.: 8210' CONTRACT DEPTH: 8500' SURFACE LOCATION: 3140' North and 1500' East from the south- west corner of Sec. 20, -T.1iN., R.12W., S.M. .suBs~u~.F.A. CE.' BOTTOM. HOL.~ LOCATION: Straight hole· ELEVATION- Ref.: K.B. +200' PROPOSED WORK: .1. Move in drilling equipment. Cellar and conductor, 30", will be installed by the contractor prior to rigging up. 2. Drill a 17½" hole to +_300'. Open hole to 26" to +--3.00'. 3.- Run +300' of 20", 945 H40 casing with guide shoe and duple--x collar one joint up. Place centralizers on the second and fourth collars. Cement through DP stabbed 'in duplex collar with neat cement until cement returns. are obtained (minimum cement required 475 sX. including ~.£' cement left in 20"). Stand cemented at least 12 hours prior to drilling out. .4. Install 20" slip weld casing head, 20"-S600 single gate with blind rams and 20"-S600 Hydril. Clean out to within 5' of the shoe with 17½" bit and test casing and BOPE to' 1000 psi, 5. Drill a 17½" hole to +2000'. Run DIL and other wire- . ~ line services· *NOTE: Place the mud logger in service at 300' LA-425 -2- 6. Run +--2000" 0f 13-3/8" 54.5~ J-55 casing with guide shoe and fill-up collar including 3 centralizers. Cement using top and bottom plugs with 1700 sx. neat cement (includes 30% excess). Do an outside job if cement does not return to the surface. Stand cemented 12 hrs. p~ior to drilling out. .. ¸. ~eck 20" x 13-3/8" annulus for gas. Tear out 20" BOP stack, install 20" x 12" spool and pack off annulus. Install 12" - S900 BOP stack. ' Clean out to within 5' of the shoe with a 12¼" bit and test the casing and BOPE to 2000 psi. Drill ahead in 12%" hole to 4000'. Reduce hole to 9-7/8" at 4000' . NOTE: A 9-5/8 ", 40,~, NS0 protective string may be run to 4000' if hole conditions demand. An 8-5/8" hole would then be drilled to T.D._~ The 20" S600 x '12" S900 spool above will hang either 9-5/8" or 7" casing. 9. Drill ahead in 9-7/8" hole to 8200' T.D- 10. Run DIL, CD~, BCS and FDL wireline logs. Shoot side Wall samples .as directed. The balance of the program and the decision Whether to run 7" casing or not will depend on logs. , NOTES: A. Mud Pro'ram .Dep,th Weiqht 0-300' - Viscositw Water Loss, 100+ 300-1900' 80-90 50-60 1900-4000' 80-90 40-50 '5-6 4000-T.D. 75 40-50 4-5 TVDe High vis.-gal wtr. Med. vis.-gel wtr. Clay-Caustic mud Clay-Caustic mud w/10%-13% diesel 1. Keep the .hole full at all times. The level in the active mud pit is to be carefully observed at all times. High pressure gas pockets are common to the area. A al.gasser is required ,from the surface to T.D. LA-425 -3- · '2. Keep the ditches less than half full of settled solids. 3. Do not Use weight materials for "dry jobs" unless · authorized by Texaco' s Drilling Foreman. B~ 4. Circulating rate and jet program should provide for a minimum annular velocity of 130'/min. and a minimum jet nozzle velocity of 250'/sec. 5. If jet program not effective or hole conditions warrant regular bits may be used. BLOWOUT PREVENTION EQUIPMENT: Texaco Class IA as 'above. Test for operation each time drill pipe is pulled. Co DIRECTIONAL PROGRAM: Take drift shots every 400'+_ on dull bit.. D. APPLICABLE STATE OF ALASKA REGULATIONS: · . 1. Cement returns or a top job required on surface casing (13-3/8"). 2. Do not drill out cement prior to 8 hrs. 3. Pressure test 13-3/8" prior to drilling out shoe. (Work order requires all strings to be tested.) E. GENERAL DRILLING SPECS BASED ON CONDITIONS IN NICOLAI CREEK STATE ~1. 1. Rotary speed 75-90 RPM. 2' Bit weight 30 to 40,000 lbs. 3. Spiral collars, and stabilizers are not required. 4. Diesel percentage (10-13%) in mud appeared to be critical below 4000'. 5. Shaffer-Wagner bumper/safety should be run directly above D.C. 6. 2-7/8" drill pipe should not be required, 7. "Limit on location fishing tools to those owned by Company. LA-425 -4- . Use 7-3/4" drill collars for drilling hole larger than 9-7/8". Use 6-3/4" drill collars for drilling 9-7/8" hole. (8-1/8°' wash pipe available for 6-1/4" collars; 7-5/8" wash pipe available for 5" .D.P.). 9., Water to be used for cement mixing should be analyzed to insure that c~ent setting time will be satisfactory. Temperature of water should be 70°F. Setting time of all c~uent jobs in Nicolai Creek ~1 was extremely slow (in excess of 48 hrs.). 10. Magniflux drill collars and subs prior to starting the well. 0-300' ~ASING DESIGN SU~;aMARY 20", 94~, H40 0-2000' '13-3/8", 54.5 , ,..7-55 0-4000' 9-s/8", 40 , u-so .0-8200' 7" casing as follows (top to bottom) 1000' 7" 26% N-80 3500' 7" 23~ N-80 2200' 7" 26% N-80 1500' 7" 29~ ~-80 JSB:rq RLP-RGB (2) -RMG-FVM 0WC-DLS-HJS-HMD JSB(2) J. S. Bathe= Field Foreman · , 37 IIIll m26 I ADL 22157 ~ $17.90 Ac. 35 ® i Atlantic Refining ADL 18774 J 800. OOAc. I1~ ISocony I ~ 160.OOAc iSocony ADL 22156 FZ~24 2.60 Ac. Q25 Texaco An.035135 1685.00 Ac. _uocony IADL22174 1160.OOAc r~exaco ' Brit. Am. · ADL 22173 532.50 Ac, 19 O0:Ac iA; 36 Texaco' Superior ADL 17598 3025.00 Ac. 3O 31 Atlantic Refining ADL 18774 Texaco Brit. Am. ADL22168 leO. OOAc, 638.70 Ac. An. 035141 290.00 Ac. 29 Texaco- Brit. Am. ADL 22172 ,.' 7 ITex --Phillips I ( -- Skelly I~ 530.00 Ac. , ! Gulf IADL;~3109 -" IAC)L03257 ! pan Am. Phillips i l60.OOAc,[Skelly Sinclair II Texaco- Shell British American ADL 22166 ADL 22167 I0 TII 21 U SS 3895 USS 4549 28 -- Texaco An. 035046 560.0015 Ac. 12W Texaco An. 035044 2204.00 Ac. oco USS 1808 55.91 Ac. .)7 USS 4550 Texaco ' Superior ADL 17585 2295.00 Ac. - i- American Phillips Skelly ,Sinclair J AOL 17586 545.00Ac.34 NOTE: LOCali~n mM'ked By I" x 2" x ~4~" stake slating well ol~ large ~0rd slake· / F ' F F NORTH le I 'o ~? I '$ IPROPOSED LOCATION I R ,~NIKOLAI CREEK No. ~'~ . Stere vision,~d that oll dim~si~s and other ~tai~ U.SC&GS, "~ FL~ [ ore correct, X · 2~3)M5.91 / ~ ~ ~ 2,565,2~26 UNION-MARATHON TRADING --~J BAY PLATFORM (center of leg) Lot. 60e 53' 48·65" Long.151e ~4' 43Jl" Y J 2,525, [26 · X · 21e,871 Long I§1° 17' 52.17" Y = 2,559,418 X = 269,652 "G~SE FLA~~~ , DETAIL / NOTES I.X and Y coordinates and bearings shown ~are based on Alaska State Plane Coor- dinate System, Zone 4. ~. Townships and ranges am based on Sewor¢ Meridian ~ Alaska. 5. Ail angles shown as turned in the field. RECEIV[D FEB 1 4 1967 OI¥1~ION OF MINES & MINE~ ~O~GE SURVEY OF NIKOLAI CREEK No. 3 LOCATED IN : SEI/4NWI/4 PROTRAOTED SEC ~'0 T N.RI2W. SM..AA~, FOR TEXACO INC. _151 5 th. Ave. ACHORAGE ,ALASK~ FIELD BOOK: J SURV!YED BY P.OPOSED LOC. ,,67 .o., EM. LIN SEYa, ASSOC. .....DATE 7 FEB. 67' ] LAND HYDROGRAPHIC j SURVEYORS SCALE I"= I MILE j POBOX 4-081 / - 11188
