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209-067
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 ti OF TtJ w� THE STAT • Alaska Oil and Gas 7LAsKAL� of Conservation Commission - tEt-_ _ 333 West Seventh Avenue iemor- � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `'T*a Main: 907.279.1433 ®FALASlAtJ' Fax: 907.276.7542 www.aogcc.alaska.gov SCOW JUN 1 82U1h George Pollock Operations Consultant Amaroq Resources, LLC PO Box 90225 Anchorage, AK 99509-0225 Re: Nicolai Creek Field, S. Undefined Tyonek Gas and Beluga Undefined Gas Pools, Nicolai Creek 11 Permit to Drill Number: 209-067 Sundry Number: 318-229 Dear Mr. Pollock: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this (Z day of June, 2018. RBDMS. JUN 13 as • 110 kC� S STATE OF ALASKA 5 Y,, G 1 2018 rates ALASKA OIL AND GAS CONSERVATION COMMISSION G ( i 21 ► APPLICATION FOR SUNDRY APPROVALS L I m s ' 20 AAC 25280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ CT Cleanout w(N2 ❑ - 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Amaroq Resources,LLC Exploratory ❑ Development ❑• 209-067 - 3.Address: PO Box 90225 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99509-0225 50-283-20135-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Nicola'Creek#11 - Will-planned perforations require a spacing-exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): „S'- uiJ ' 'ja-cr1;,_/4-y ADL 391472 ` Nicola'Creek Field Beluga eggi Undefined Gas/5'-i,s"-V-45) 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MED Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 3600' 3600' , 3509' 3509' 250 psi None 24746 Casing Length Size MD TYD Burst Collapse Structural Conductor 102' 13 3/8"688 K55 , 102' 102' 3450 psi 1950 psi Surface 632' 95/8"36#K55 632' 632' 3520 psi 2020 psi Intermediate Production 3589' 5 1/2'17#J55 3509' 3509' 5320 psi 4910 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 920'-2362' 920'-2362' 2 7/8" 6.5#J55 2183' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydraulic and mechanical 'Hydraulic©909',1297'&1690';mechanical @ 2175' 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 1 13.Well Class alter proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service 14.Estimated'Date for 15-Jun-18 15.Well Status after proposed work: Commencing Operations: OIL. D WINJ ❑ WDSPL 0 Suspended El 16.Verbal Approval: Date: GAS ❑ ` WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 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: Operations Co ultant Contact Email: QpoIIOCk(U7aurorapower.corn Contact Phone: 907.351.8286 Authorized Signature: Date: 31-May-18 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Q Q Plug Integrity❑ 80P Test Mechanical Integrity Test ❑ Location Clearance ❑ , Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: G I 1 7..-)1 \0, �2 el7�r t1-/8' ORIGINALRBDS � >/-45 and 1 ) Form t0-403 Revised 4/2017 Approved application Is'validr12 MIrom the date app a.JV ? 3 2O1 clime Duplicate icate b ,vI A • • AMA OQRESOURCES„LLC NICOLAL CREEK 11 CTU CLEANOUT Scheduled Spring 2018 (4/5/18) STATUS OF WELL: Live-well flo-wind.150 MCF/D-at 60 psi-(165_psi SITP),with - sand/mud fill at-+-/- ,1,7.02' / //PIP = 250 si CASING: 5-1/2 inch 17#,J-55 casing set at 3,589' (Capacity=0.0232 bbl/ft), PERFORATIONS: 920-30', 1004-12, 1.090-1100, 1208-16' 1349-1355, 1388-1402', 1414-34', 1658-75 1736-41', 1752-57', 1763-68', 1810-30', 2058-63', 2089-99' 2260-74', 2345-2362' -PAC cS: 909'_,=1297'_,1.690'3&1175' TUBING: 2-7/8"6.5#J-55 EUE (Capaci =0:0OS796-bbI/ft).. EOT=2,185' w/ Sliding Sleeves with X-Profiles(2.313") at: 900' (casing fluid--closed), 979' (tested water and sand dosed), 1619' (closed), 1701' (open), & 2014' (open,but_co-vered with fill). Tubing leak at+/- 1645',tibing patch not currently installed 3-1/2"Strata Pack Screens cut off at 2185', chased fish to 2474'. � I SUMMARY OF PLAN: Close open sleeve at 1704', RU CTU and clean out fill in tubing. Run thru end of tubing and cleanout to TOF at 2474'. Test well to determine which zone(s)to leave open and if tubing patch to be installed. PROCEDURE: 1) RU Pollard. Shut-in well,run 2"bailer to tag and sample fill. Fill expected at 1702'. POH. Bail to below 1710'KB, if necessary. 2) Run shifting tool and close sliding sleeve at 1701'. 3) POH and remove wellhouse and set off the side of the location. 4) RD Pollard—but have then^.standby (on west side—do other work). 5) Grease Wellhead Valves really well. 6) MI and RU Coiled`Tubing Unit w/ 1,1/2" coil,crane,and spot N2 unit. MU AG choke skid and flow back iron to SSV on wellhead or flowback tee on BOP skid and flowback tank. For CT cleanout, use clean(no oily) PW from NC11 in Tiger Tank on location(approx. 75-150 bbls). _a) _Fill_coiled_tubing_reel_noting volumes-on Barrel counter i=displacement_tanks. Compare with theoretical coiled tubing reel volume. b) Make up-coil connector and pull test to 10,000 lbf. Pressure test connector to 200 PSI& 4,500 PSI for 10 and Kt minutes respective)'. • ) Make up-BHA::Dimpleon connector, dual flapper check, Hyd disconnect, straight bar, and 1.75"Wadi=Nozzle and measure/record art-4:41'OD's,ID's,&lengths. • Note: Ensure company rep verifies and is in agreement with BHA to be run.Compare maximum OD of tools°mak minimum ID of the well completion(2.313") d) Nipple up BOP stack to wellhead – 2-9/16" 5000# RTJ Flange (XO available from Vetco). Notify state 24-48 hrs prior to testing BOP's ) Pressure test via:CT, pumps,.stack,:flow back_manifold_against crown-valve-to.200:PS1 &4,500 PSI for 10 and 10 minutes respectively. f) If running a check valve, bleed pressure through flow back manifold.to 1,000 psi and inflow double flapper check valve by bleeding off coiled tubing pressure via the reel manifold. • Note: take care that excessive stripper pressure is not applied that can cause pipe collapse::scenarios. g) On completion of all tests re-pressure up via coiled tubing to equalize to crown valve andopen up tree valves h) Displace the coiled tubing to the fluid required for the job 7) RIH and clean out sand to EOT,then to top of fish circulating while RIH with PW. a. Begin RB-i @ 100 fpm.and 10 fpm at restrictions b. While running in hole, circulate fluid at rate to prevent nozzle plugging. Generally 0 25bbl/min. c. Run in hole to a depth of 1500 ft and perform pull tests(or more often if the company representative/supervisor feels it necessary.) Increase fluid to 0.75 -bbl/min. Compare-results.with Modeling :predictions. Slow down to:10:ft/min_until fill is tagged. d. Reduce the penetration rate to 5 fpm while washing formation sand/debris. e. The coiled tubing operator should perform pull tests as required and back jetting passes when washing through the fill to establish that the coiled tubing is free from obstructions. f. Monitor the returns at surface to establish the fill removal efficiency. g. When tubing has cleaned out below sleeve at 2014',P001-1 w/CT. RU Pollard and close sleeve at 2014'. RD Pollard. h. Continue with CT cleanout—RIH w/CT. When the tubing has reached the desired depth.(2474-ttestimated-top-of_flsh)circulate ter 30-min.w/-cl.ean_PW and ensure that fluid coming back is sand free.up 1. Pull up to sleeve at 2014' and circulate clean,run back to bottom and circ clean. • • 3. Start the tlow of N2 and unload the fluid from the well, POH while pumping N2. k. When at surface close in at the wellhead leave about (200 psi on the tree when fimished)&bleed surface equipment down,rig off well head. • Note: Wellhead pressure during a cleanout should be kept above 150 psi to reduce erosion. Nate:If too_ntach fill is attempted to be-removed too_quickly it can cause loss of circulation of the fill out of the weillore.This could allow the fill to fall hackie the annulus,sticking the coiled tubing in the well. If this occurs pull above the perforations or further until circulation is restored. Once Circulation is restored circulate a complete wellbore volume at the specified depth and once it is dear of sand proceed into the well. Also if lost circulation is encountered call the engineer immediately. If bridges of fill areencauntered, be aware of the possibility ofpressure being_trapped below the bridge.Maintain sufficient back pressure to protect the coiled tubing from a possible kick.If bottom hole pressures are not known there is a possibility of no pressure below the plug and,once the coiled tubing breaks through,alt the circulating fluid with fill falling back down the hole trapping the culled tubing.In this case,lifting small amounts of fill and circulating it out of the well may be advisable prior to proceeding too deeply into the fill. &) RI) Coiled Tubing Unit. 9) RU Pollard. Rift with223" LIB and tag water level. 10)With AG operators, try to flow well,monitor gas and water flow rates call me to discuss. 11)Determine if sleeves 2014' and/or 1701 should be re-opened. If not,release Pollard and flow well to production. If so, pull tubing patch, open sleeve(s), re-install tubing patch,put on production and test. Ed Jones(3/2-6/13)Revised George Pollock-415/18 • • 2 7/8 63#8rd EIDE J-55 Aurora Gas, LLC 1 Nicoiai Creek#11 Final Actual Completion Sept 2009 Update 04/1813-38" 68#K-55 Conductor CTCO Performed 8/2014 driven to 102' RKB-16.Oft GLE:+4'MSL Drill 12-1/4"Hole to 650' Beluga Tops - Tsuga 2.5-780' 9-5/8"36#K-55 Surface Casing set at Tsuga 2.6-1076' 632' Tsuga 2.7-1298' Cement w/13.0 ppg accelerated Type 1 Tsuga 2.8-1912' Tyonek Tops , Cary*2-1.1-2258' ►i1 WXA Sliding Sleeve @ 900' Carya 2-1.2-2344' PIMP Ilydraulie-Set Packer*909' '13, WXO Sliding Sleeve @979' (CLOSED) UPPER Tsuga 2.5 COMPLETION:920-930' 10044012' Tsaga 2.6 -�• 1099-1100' 12084216' . PIIRP Hydraulic Set Packer @ 1297' UPPER MIDDLE Tsuga 2-7 ' WXO Sliding Sleeve @ 16W(closed) COMPLETON:1349-1355' 1388-1402' Thru-tbg patch set at 1641-58'across 1414-1434' suspected tubing leak-not currently 1658'-1675' - tB installed =r ; PHRP Hydraulic Set Packer @.1690' LOWER MIDDLE Tsuga2-7 T - COMPLETION: 1736'4741' 014 1763-1768'_ „ . 1 WXO Sliding Sleeve @:170V_(open). 1810-1830' Tag fill@ 1702' Tsuga 2•S ER 2058-2063' = WXO Sliding Sleeve*2014'(open) 2089_2099' ' Mechanical-set Packer*2175 w/On-Off Tool !a 2173'w/X Nipple ' LI 2 7/8"pup cut*2185' With 2ea 34/2"Stratapak screens'ii. 2234' with 2-7/8"pup with no bull plug in bottom. LOWER Carya 2-1 111 COMPLETION: 2260-2274' Iiii a Fish @2474' 2345-2362' "" :: -...... Ill. 4 NI 554"17#J-55 Casing to 3589'MD(TVD) Cement w/48 bbl 12.0 ppg+95 bbl 14.8 ppg PBTD @ 3,509' Class`G'tail. Drill 7-7/8"Hole to 3,600' 1 • 1 • Client; Arms aroq Resources Schlanterger Coiled Tubing Services Date: May a15t 201a Pressure Category 1 BOP Configuration Drawn: Chad Barrett g � g Revision: 0 (0-3,500 psi) Well Category: CAT I .:£ . liII t .71.E eS1rr x- i lliiti .40 ■ �'- "+? �"a ti ,gam... v'� u. ',k .:sNs MMitrfi,:afIiTLiallIMIl1 I lP "-!� = Fs/ X111@y' 10r' ►y i milli lar bi -- f, ' ' r -Kill Pert WH,P61 4i4 2"1502 x 2-1/16 10K gni Flanged Valve .Ott.', ', e AN t $ n} #(Manual) u '2-9/ . � MI 46 1OK x-2-1/16 0 rm.- sr - 1 '''-t7,.3 ,� rk a10K Flanged Valve I " poo ,�(Mazuali aa� E. ■ } . 0eawE .�■net y- -� -. .,,..;:. .. , i ,i ` -- et igiN--. - i. ,� u4.. ., 1Afll[ liIKD 1yItC (O 1f - Q .x a. ma „> .49Kx21116',1 ,J ee ‘1701 iit IBJ • S STANDAtiii) --WELL:-AitOCTDURE NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perforin Pre-Job Safety -Meeting. Review-Nitrogen vendor standard ,opera Mg procedures and'ate Safety Data Sheets(fonnerly MSDS),. 4.) Document hazards and mitigation measures and .confirm flow pathsknelude review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. -Spot Tunwing Unitand transport.-_Contirm;liquid-N 2--_v°lames-;in;transport. 6.) Rig up lines fix=the Nitrogen Pumping unit to the well and returns tank Secure lines with whip checks. 7.) Place signs and placascis wad/pkg.of MO pressure and rittrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure _ttibing-and-raSing:pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.)Wellsite Manager shall walk down valve alignments and ensure valve position(iseorrect. 11.)Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector:as meitthatmeasures;02;levels. 12.)Pressure test lines upstream of well to approved sundry pcessure or MPS?' iMac Potential Surface Pressure), whichever is higher. Test lines downstm of well (from well to returns tank).to.1,500 psi.Perform visual inspection for any leaks. 13.)Bleed off test pressure and prepare for pumping nitrogen. 14.)Pump nitrogen at desired rate, monitoring rate (SCFM) and Tressure (PSI). Alt nitrogen returns are-to be routed to theraturnstenk. 15.)When final nitrogen volume has been azhieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.)Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. il7)iFinalize job lig.and-:discuss :operations -with-Wellsite -Manager. :Document:any iLessons learned and eonfirm final rates/pressure/volumes of the job.and remaining nitrogen in the transport. 18.)RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport* y, Tkr, I//7: A THE STATE Alaska Oil and Gas ,,s��� of e ee ((�� �� ®®V���l Conservation Commission A�Il � ! 333 West Seventh Avenue Vigil* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FA .S ' Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock ManagerSCAsNsAIL A 20 1;`, Aurora Gas, LLC 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Nicolai Creek Field, Beluga Undefined Gas Pool,Nicolai Creek 11 Permit to Drill Number: 209-067 Sundry Number: 317-281 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, d09:1\ Hollis S. French Chair DATED this day of July, 2017. RBDMS L JUL 1 1 2017 � V STATE OF ALASKA J Li N 16 ?_017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS t 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Weil ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ 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 Q, 209-067 ` 3.Address: 1400 W.Benson Blvd.Suite 410 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-283-20135-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NT Nicolai Creek#11 Will planned perforations require a spacing exception? Yes ❑ No Z- .?/11) 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 1�6.8&& 39 /41 7-2_ P 3 Nicolai Creek Selig Belugaaiui.Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total t ito J whoMD(ft): Total DrgU1OT�/B(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 35 ' /K/y3 3509' , , 3509' 250 psi None 2474' Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 13 3/8"68#K55 102' 102' 3450 psi 1950 psi Surface 632' 9 5/8"36#K55 632' 632' 3520 psi 2020 psi Intermediate Production 3589' 5 1/2"17#J55 3509' 3509' 5320 psi 4910 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 920'-2362' . 920'-2362' 2 7/8" 6.5#J55 2183' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydraulic and Mechanical packers Hydraulic @ 909',1297'&1690"and Mechanical @ 2175' 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development❑ • Service ❑ 14.Estimated Date for TBD 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS [] • WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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 George Pollock Contact Name: Authorized Title: Manager-P7' 0.. ung Contact Email: gpollock(a7aurorapower.corn Contact Phone: 907-277-1003 Authorized Signature: r Date: 16-Jun-17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 ( 7- 2� � Plug Integrity ❑ BOP Test [] Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1'[MMP i.2Jtt'Ll.f' -,F`.. 6.„ tx.L> vac,c (Z,C x;,tiz.eMl't o GS tZ .r0t,E'e,`<,top_i Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Wr Subsequent Form Required: 'C) _404_ RBDMS t L JUL 1 1 2017 APERO Y -4 1-3 liq Approved by; JCOMMISSIONER THE COMMMM ISS SION Date; ^ okR,44illsi,Altd (i Submit Form ane `��0 1a-aOs Revi��17 for 12 months from the date of approval. Al 7�iAttachments in Duplicate M • Aurora Gas, LLC June 16, 2017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 JUN 16 Z011 Re: Application for Sundry Approval—Set Temporary Plug AOG CC Nicolai Creek#11 Well PTD #: 209-067 API #: 50-283-20135-00 Dear Ms. Foerster: Aurora Gas, LLC hereby requests approval to set a temporary plug to secure this onshore development well in the Nicolai Creek South Beluga and Undefined Gas Field on the west side of Cook Inlet, southwest of the Village of Tyonek. This well is currently producing gas from multiple zones in the Beluga and 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 900' 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. Sincerely George 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 . 2 7/8 6.5#8rd EUE J-55 1 Aurora Gas, LLC , ' ' P ;._ Nicolai Creek#11 {' Final Actual Completion ' • 13-3/8" 6811 K-55 Conductor September 2009 Update 8/14x driven to 102' RKB—16.0ft GLE:+4'MSL Drill 12-1/4"Hole to 650' Beluga Tops Tsuga 2.5-780' '"' 9-5/8"36#K-55 Surface Casing set at Tsuga 2.6-1076' 632' Tsuga 2.7-1298' Cement w/13.0 ppg accelerated Type 1 Tsuga 2.8-1912' Tyonek Tops Carya 2-1.1-2258' ►l; WXA Sliding Sleeve*900' Carya 2-1.2--2344' PHRP Hydraulic-Set Packer fg,,909' i}` WXO Sliding Sleeve @ 979' (CLOSED) UPPER Tsuga 25 _r„_ C= Opened 1/13 made sand and water COMPLETION:920-930' . 1004-1012' Tsuga 2.6 ' 1090-1100' 1208-1216' PHRP Hydraulic Set Packer 1297' . UPPER MIDDLE Tsuga 2-7 WXO Sliding Sleeve*1619'(closed) COMPLETON:1349-1355' (sleeve seems to be leaking) 1388-1402' 1414-1434' 1658'-1675' il. , .-.■moi alai..-- PHRP Hydraulic Set Packer*1690' LOWER MIDDLE Tsuga 2-7 COMPLETION: 1736'-1741' 1152-1757 WXO Sliding Sleeve(a?1701'(open) 1763-1768' 1810-1830' Tsuga 2-8 NO Sliding Slee)a'a 2014'(open?) 2058-2063' i= 2089-2099' r' Mechanical-set Packer nn, 2175 w/On-Off Tool @ 2173'w/X Nipple 2-7/8"tubing pup cut at 2183' CT CO August 2014 to 2440' ■ 1:::. 51"fish incl 40"3 Y2"Stratapak screens y�..y, with 2 7/8"pups above&below with bull LOWER Carya 2-1 s ... plug in bottom.TOF 2474'WLM COMPLETION: 2260-2274' III 2345-2362' 5 Y:"17#J-55 Casing to 3,589'MD(TVD) A Cement w/48 bbl 12.0 ppg+95 bbl 14.8 ppg PBTD @ 3509' Class`C.'tail. Drill 7-7/8"Hole to 3,600' • 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 1/2"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. ,C�y�e .Sana fe (6/11/2017) • 110 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. We ll History File Identifier 9 7 Organizing (done) Two -sided III I1 11111 1111 ❑ Rescan Needed II I11111 III I I RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Map : reyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner I_ OG.Jc ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Ad. Date: 6 / 3 /s/ mP Project ject Proofin III [1111 I 111 I Proofing BY: AM Date: 5 1 1 3 Is/ Scanning Preparation `T x 30 = l c © + 3 = TOTAL PAGES 1 a3 BY: Date: 5 13 (Count does not include cover sheet) /s/ Production Scanning I I 11111 Stage 1 Page Count from Scanned File: / a, (Count does include cov sheet) in Scanning Pre Page Count Matches Number g aration: YES NO p BY: Maria Date: S i 1 f i 3 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 11111111111i ReScanned II 1111111 It'll BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111E11111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/8/2013 Permit to Drill 2090670 Well Name /No. NICOLAI CREEK 11 Operator AURORA GAS LLC API No. 50- 283 - 20135 -00 -00 MD 3600 TVD 3600 Completion Date 9/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log 40, - Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: CST, XPT, DIP METER, PRESS EXP, HOR, MUD LOG (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Log Mud Log 2 Col 110 3600 Open 10/2/2009 mud log Log t� Mud Log 5 Col 110 3600 Open 10/2/2009 mud log EDIX Pds 18720 Induction /Resistivity 20 3538 Open 10/2/2009 XPT, PEX, FMI, CST in graphical form (PDS) only Rpt ✓ Pressure 923 3391 10/2/2009 Data Eval Report ED C Las 18721 Pressure 923 3391 10/2/2009 Data Eval Report Log ✓ Induction /Resistivity 25 Col 20 3538 Open 10/2/2009 Plat Ex, AIT, RHOZ, 1 NPOR, PEF, CAL, GR, SP Log Sample 5 Col 923 3391 Open 10/2/2009 MD CST, GR Log 1 Pressure 5 Col 923 3391 Open 10/2/2009 Express Pres Tool, GR LLog./ / � Dip 5 Col 1500 3532 Open 10/2/2009 FMI Dip, GR ED rC Las 19179 Induction /Resistivity 6 3549 Open 1/7/2010 GR, Tens, ICV Well Cores /Samples Information: • Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings .— - 90 3600 9/17/2009 1336 v - ADDITIONAL INFORMATION ('� Well Cored? Y , l .. � \4 ... �t Daily History Received? ( � Chips Received? af" / Formation Tops `� "' Analysis 171T Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/8/2013 Permit to Drill 2090670 Well Name /No. NICOLAI CREEK 11 Operator AURORA GAS LLC API No. 50- 283 - 20135 -00 -00 MD 3600 TVD 3600 Completion Date 9/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N Compliance Reviewed By: Date: 20 • ' STATE OF ALASKA ALASKP- AND GAS CONSERVATION COMMISSO GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. Test: 151 Initial II Annual • Special 1b. Type Test: • Stabilized • Non Stabilized 0 Multipoint ❑ Constant Time ❑ Isochronal ❑ Other: 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Aurora Gas, LLC 6- Oct -09 209 -067 3. Address: 6. Date TD Reached: 12. API Number: 1400 West Benson Blvd., Suite 410, Anchorage AK 99503 September 12, 2009 50- 283 - 20135 -00 -00 4a. Location of Well (Governmental Section): 7. KB Elevation above MSL (feet): 13. Well Name and Number: Surface: 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. 16' (DF) Nicolai Creek #11 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. 3,509' MD & TVD Beluga undefined Gas Field & Total Depth: 9. Total Depth (MD + TVD): Nicolai Creek South Undef. Gas 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. 3,600' MD & TVD Field 4b. Location of Well (State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 2564934.415 y- 1379809.804 Zone- 4 DNR Lease ADL- 391472 TPI: x- 2564934.415 y- 1379809.804 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 2564934.415 y- 1379809.804 Zone- 4 Multi- packer Selective w/ Sliding sleeves (4- separate zones) 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 5-1/2" 17# 4.89" 3,589' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 1736 -41, 1752 -57', 1763 -68', 1810 -30', 2 -7/8" 6.5# 2.44" 2,234' 2058 -63, 2089 -99, 2260 -74', 2345 -62 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocarbons: 23. Specific Gravity Flowing Fluid (G): 909', 1297', 1690', 2014' N/A N/A 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): 0 Tubing ❑ Casing 87 F° 924 psia @ Datum 2,049 TVDSS 14.65 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H2S: Prover: Meter Run: Taps: 2,234 2,234 0.559 0 1.003 0 Daniel Sr. 4.026 Flange 26. FLOW DATA TUBING DATA CASING DATA Prover Orifice Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line )( Hr. Size (in.) Size (in.) psig Hw F psig F psig F 1. 4 X 1.75 253.26 7.08 40 780 51 1 hr 2. 4 X 1.75 465.55 19.18 42 695 51 1 hr 3. 4 X 1.75 427.15 32.49 45 621 52 1 hr 4. 4 X 1.75 507.59 38.44 45 571 53 1 hr 5. X Basic Coefficient Flow Temp. Super Comp. Rate of Flow Pressure Gravity Factor No. (24 -Hour) h Factor Factor O Mcfd Fb or Fp Pm Ft Fg Fpv 1. 15.31 43.53 267.91 1.002 1.336 1.001 893 2. 15.31 95.96 480.2 1.018 1.336 1.001 2,001 3. 15.31 119.80 441.8 1.015 1.336 1.001 2,490 4. 15.31 141.68 522.24 1.015 1.336 1.001 2,945 5. Temperature No. Pr Tr z for Separator for Flowing T Gas Fluid Gg G 1. 0.9981 0.559 0.559 2. 0.9981 0.559 0.559 3. 0.9981 Critical Pressure 0.559 0.559 4. 0.9981 Critical Temperature 0.559 0.559 5. Form 10 -421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Su ' 'n Duplicate RBDMS FEB 2 3 2010 _ r ` Pc 882 p 777924 • Pf • 924 Pf 853776 No. Pt Pt pc Pw pw Pc Ps Ps Pf -Ps 1. 782 611524 166400 39 1521 776403 821 674041 179.735 2. 707 499849 278075 40 1600 776324 747 558009 295.767 _ 3. 638 407044 370880 38 1444 776480 676 456976 396.8 4. 588 345744 432180 40 1600 776324 628 394384 459.392 5. 25. AOF (Mcfd) 5466 n 1 Remarks: AOF & n: Calculated using Ryder- Scott Reservoir Solutions Software, see attached. hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , Title Mgr. Production Ops & Eng Date 2/22/2010 DEFINITIONS OF SYMBOLS AOF 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 Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= - 1' dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air= 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z 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. Form 10 -421 Revised 7/2009 Side 2 T +P 0 a r : f r 4'#F 4 1 [..N Er I/✓'C1[ C`I K #t1 i ' , �� R ery 3 FIE LD NICO C RE E K . �� iii , �� E.O� It?N West Side Cook inlet, Kenai Bor., Alaska . r � � ERV t 1. T s ug a 2 -7 Tsuga 2 8 Carya 2 1 1 and 212 (P er '1736- 2382} s f y E y : 3 rs •'• r z. .., r_> it B OTTC? : : LE T M � ° 87 �€3UR:G MOLD `ii��i�iii ;il . ��_■■1111� ���1l1111 � GPI f 580 N 1 � ••ii1111� •! ©81111 y y Vrfl 1 010 CO2 . 0(Q � • 0 � �UU l 111111 �� i 1 x � TVD F .0.,11.,..4! � � � � ME1 i D TH 2449 OP11 ©r1 ' f " r■ , p� A ° a rc N y ; a e PSf1 A 1 L-triliP!!!!"1:411Atilill1)!ti � :37 a Pl tj� 4: ; a te y r ` 4 60 - ;9 s � g Yy. � � SULTS �v ,E E a • A OF 4 sP�% h .rr? ,i a � \ ., ,s_ h .� :, E `� l i "` .:. __ k., n,. 'si° y E: � POINT NO. Test Data F LOWIN G r y (Automatic) Q, Mcf /d BCPD BWPD FTP, Psia WHT, ° BHP, Psia COMMENT 9 y 9 „ SHUT -IN 0 0 0 882 40 924 SIBHP ! : !ii 1 893 0 4 782 51 821 11141f, 4i-s% Olt 2,001 0 13 707 51 747 3 2,490 0 5 638 52 676 Ir011itili. ...,.„,„„4„141741,14:494%„•,k: iltillIlliilIlltIIIMIMINIIIIg12158""'a 4 2,945 0 6 588 53 628 �� These results were pr epared u sing Reservoir Solutions Software. This is not Ryder Scott work product. Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, January 07, 2010 2:11 PM To: 'Bruce Q Webb' Subject: Received Nicolai Creek 11 (PTD 2090670) LAS Files CD Bruce, Thank you for delivering the CD containing the digital PEX and FMI data (in LAS format) for Nicolai Creek 11 this afternoon. I appreciate your help in obtaining these files. Thanks again, Steve Davies AOGCC cog -0 19/ • STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION `' WELL COMPLETION OR RECOMPLETION REPOT ;Q (Animism( la. Well Status: Oil ❑ Gas 0 SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: ll Aurora Gas, LLC Aband.: Sept. 23, 2009 209 -067 / 3. Address: 6. Date Spudded: 13. API Number: l 1400 West Benson Blvd, Suite 410 Anchorage, AK. 99503 September 1, 2009 50- 283 - 20135-00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. September 12, 2009 Nicolai Creek #11 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field /Pool(s): 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. 16' AMSL (DF) Total Depth: 9. Plug Back Depth(MD +TVD): Beluga Undefined Gas Field, and 1,894' FSL, 1,534' FEL, Sec. 30, T. 11 N., R. 12 W., S.M. 3,509 TVD & MD Nicolai Creek South Undef. Gas Field 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 2564934.415 y- 1379809.804 Zone- 4 3,600 TVD & MD ADL- 391472 TPH: x- 2564934.415 y- 1379809.804 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 2564934.415 y- 1379809.804 Zone- 4 N/A DNR Lease 18. Directional Survey: Yes ❑ No 111 19. Water Depth, if Offshore: 20. Thickness of Permafrost MDTTVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re -drill /Lateral Top Window MD/TVD: Schlumberger: Platform Express, CST, XPT, Dip Meter, Pressure Exp. Horizon: Mud Logs. N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMT CASING FT GRADE TOP BOTTOM f TOP BOTTOM HOLE SIZE CEMENTING RECORD PLO 13 -3/8" 68.0# K -55 surface 102' surface 102' driven n/a 0 9 -5/8" 36.0# K -55 surface 632' surface 632' 12 -1/4" 103 bbl, 13.0 ppg Class G 0 5 - 1/2" 17.0# J - 55 surface 3,589' surface 3,589' 7 - 7/8" 143 bbl, 12.0, 14.8 ppg Class G 0 13, 24. Open to production or injection? Yes El No ❑ If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) / 920' - 930' TVD & MD, 3.5 ", 6 spf 2 -7/8" 2,234' 909', 1,297', 1,690', 2,175' .i 1,004' - 1,012' TVD & MD, 3.5 ", 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1,090' - 1,100' ND & MD, 3.5 ", 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1,208' - 1,216' TVD & MD, 3.5", 6 spf 1,349' - 1,355' ND & MD, 3.5 ", 6 spf 1,763' - 1,768' ND & MD, 3.5 ", 6 spf 1,388' - 1,402' ND & MD,•3.5 ", 6 spf 1,810' - 1,830' TVD & MD, 3.5 ", 6 spf 1,414' - 1,434' ND & MD, 3.5", 6 spf 2,058' - 2,063' ND & MD, 3.5 ", 6 spf 1,658' - 1,675' ND & MD, 3.5 ", 6 spf 2,089' - 2,099' ND & MD, 3.5 ", 6 spf 1,736' - 1,741' ND & MD, 3.5 ", 6 spf 2,260' - 2,274' ND & MD, 3.5 ", 6 spf 1,752' - 1,757' ND & MD, 3.5 ", 6 spf 2,345' - 2,362' TVD & MD, 3.5 ", 6 spf 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 9/24/2009 flowing Date of Test: Hours Tested: Production for —. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 10/6/2009 10 Test Period ...nip. 0 2,190 mcf /d 7.2 bbls/d 2 ", 20 -24 bean N/A Flow Tubing Casing Press: Calculated - Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 683 0 24 -Hour Rate -♦ 0 5,904 mcf /d 10 bbls/d n/a 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No ig If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of o'; sAir_" , 4 (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results pert 0 • . f • $ %i` No cores taken. RBDMS JAN —5 2010 „ Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes - No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top n/a n/a and submit detailed test information per 20 AAC 25.071. Permafrost - Base n/a n/a 10/06/09: Perform 4 point test Beluga Tsuga 2 -5 780' 780' Beluga Tsuga 2-6 1,076' 1,076' ISIP - 564 ia. Beluga Tsuga 2 -7 1,298' 1,298' Beluga Tsuga 2 -8 1,912' 1,912' Flow well until stable at 4 points: Tyonek Carya 2 -1.1 2,258' 2,258' 949 mcfpd at 796 psia w/ 4.48 bwpd; Tyonek Carya 2 -1.2 2,344' 2,344' 2,073 mcfpd at 709 psia w/ 13.50 bwpd; 2,593 mcfpd at 638 psia w/ 5.05 bwpd; 3,143 mcfdp at 590 psia w/ 5.76 bwpd. (CAOF =5,904 mcfpd) Formation at total depth: 3,600' 3,600' 30. List of Attachments: Daily Operation Summary. Well Schematic and Logs (previously submitted under separate cover) 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aurora Gas, LLC Printed Name: Bruce D. Webb , � Title: Manager, Land and Regulatory Affairs Signature: ��/eS Phone: (907) 277 -1003 Date: 1/4/2010 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 7/2009 • • AURORA GAS, LLC NICOLAI CREEK NO. 11 (AOGCC PERMIT No. 209 -067) (API No. 50- 283 - 20135 -00) DRILLING, COMPLETION, AND TESTING OPERATIONS SUMMARY 8/10 - 25/09— Construct road and pad. 8/26/09 —Set liner and mats for rig 8/27/09 —Move in rig and related equipment and start rig up. 8/28/09— Continue move in and rig up. 8/29/09 Continue move in and rig up. Cut conductor and install slip -on head. Install diverter spool. 8 /30 /09— Continue rig up. NU diverter stack and system. 8/31/09— Continue rig up. Function test diverter -- witnessed by Bob Noble of AOGCC. V 9/1/09— PU 12 -1/4" bit and 6 -1/4" DC's. Clean out conductor to 109'. SPUD —drill new hole to 127'. POH. PU 8" DC's & stabilizers. RIH. Drill to 135'. MW -10.0 ppg. 9/2/09 —Drill to 321', losing 20 bph of mud since 200'. Mix & pump LCM sweep and reduce ECD. Control drill to 507', adding LCM and building mud volume. CBU. Survey -0 deg. Drill 507 to 600'. MW -10.0 ppg. 9/3/09 —Drill to 650'. CBU 3X. Wiper trip. Weld support plate on conductor. POH, LD 8" DC's and stabilizers. RU GBR. Run 16 jts 9 -5/8" 47# & 53# L -80 BTC casing to 631'. Circ and condition. RD GBR. RU BJ. Test lines to 2000 psi. Pump 25 bbl spacer. Attempt to pump cement —BJ truck lines plugged. Attempt to remedy w/o success. Replace pump truck. MW -10.0 ppg. 9/4/09— Replace BJ pump truck. Pum 103 bl (578 cf /317 sx) light Type I cement at 1.82 cf /sk yield and 13.0 ppg, displace g pump. Cement to surface after 200 sx pumped. Bumped plug at 500 psi. Floats held —bled off pressure. Circ 27 bbl (83 sx) cement to surface. WOC. RD cementers. Start ND diverter. Make rough cut on 9 -5/8 ". Finish ND diverter. 1 • • 9/5/09 -Final cut of 9 -5/8" casing. Weld on head. Allow to cool 6 hrs, Test to 3000 psi -OK. NU BOP. Start BOP test to 250/3000 psi. 9/6/09- Finish test BOP's to 250/3000 psi. PU & strap 7 -7/8" BHA. RIH to 582'. Circ f and condition mud. Tag cement at 582'. Drill to 587'. Test casing to 1500 psi f/ 15 min. -OK. Drill FC, cmt, FS, & 20' new hole to 670'. MW -10.0 ppg. 9/7/09 -LOT to 204 psi w/ 10.0 ppg mud -15.4 EMW. Diplace mud w/ new EZ KC1 mud. Drill to 752'. Clean mud pits and build more volume. Drill to 1032'. WL single - shot svy -2 attempts -7 deg - misfires. Drill to 1094'. WL svy at 1063' -0.75 deg. Drill to 1157'. Short trip to 595'. Circ out gas at 727' -770 u. RIH to btm -CBU -170 u gas. Drill to 1400'. MW -10.2 ppg. 9/8/09 -Drill to 1531'. Svy at 1496' -1 deg. Drill to 1656'. CBU 2X w/ nut plug sweep (bit balling). 10 std wiper trip to 1058'. Drill to 2030'. Svy at 1996' -- -2.75 deg. Drill to 2092'. MW -10.2 ppg. 9/9/09 -Drill to 2157'. CBU 2X. 11 stand wiper trip to 1468'. Drill to 2528'. Svy at 2497' -4 deg. Drill to 2622'. MW -10.2 ppg. 9 /10 /09- Drillto 2655'. CBU 2X. Short trip to 2000'. Drill to 2808'. Drop svy. POH for new bit. Took 7 bbl gain at 627'. SI well -SICP -110 psi, SIDP -100 psi. Circ out gas thru gas buster. Mix and pump 15 bbl 13.1 ppg pill. No flow. RIH 5 stds, circ well w/ 10.4 ppg mud. No flow. POH. PU new bit. Svy -5.5 deg at 2800'. RIH, tight. 10.4 ppg. 9 /11 /09- Continue RIH to 2808' w/ tight spots. CBU w/ 996 u, 410 u, and 132 u at 700', 1400', and 2040' respectively. Drill to 3183'. MW -10.2 ppg. 9/12/09 -Drill to 3340'. CBU 2X and run WL svy at 3305'. Drill to TD of 3600'. CBU. Mix and pump high -vis pill. POH to 2373' w/ tight spots at 2820', 2775', & 2560' (35 -40K OP). MW -10.2 ppg. 9/13/09-Continue POH to 625'. Monitor well -OK, RIH to 3600'. CBU. Mix and pump high -vis sweep to clean hole. POH to log. Mix and pump 13 ppg pill. Continue POH. Retrieve svy tool -7 deg at 3600'. RU Schlumberger. Run PEX log. Start XPT run. MW -10.3 ppg. 9/14/09- Finish XPT run. Run tool and shoot SWC's. Run FMI in dip meter mode. RD SLB. MU clean -out BHA and RIH, fill every 500'. Wash 2 jts to bottom. CBU 2X- max gas -30 u. POH to shoe for wiper trip. MW -10.2 ppg. 9 /15 /09 -RIH, wash last jt to bottom. Pump high -vis sweep and circ clean. Mix and pump weighted "dry job' pill. POH to run casing. Stop at 650' and spot 20 bbl 13 ppg pill. Fin POH. LD BHA. Change to 5 -1/2" rams, test to 3000 psi. RU to run casing. Start running 5 -1/2" casing. MW -10.2 ppg. 2 • 9/16/09 —Fin running 71 jts (2759.5') 5 -1/2" 17# N -80 LTC casing + 18 jts (829.2') 17# J -55 LTC casing (on top) to 3589'. Circ and condition. RD GBR. RU BJ. Tes Drop btm plug w/ 3 bbl water. Load top plug. Pump: 43 bbl 11.5 ppg spacer + 43,14)1 (106 sx) Light Class G lead cement at 12.0 ppg/ 2.28 cf /sk 95 bbl (395 sx) Type I tail cement at 14.8 pPg/ 1.35 cf /sk. Drop top plug. Displace 8bbl brine. Bump plug /w 1500 psi —held 5 min, then release —floats held w/ V2 bbl bleed back. Cmt in place at 1000 hrs. Place slips to center casing. WOC 12 hrs. Set slips w/ 80k. ND BOP. 9/17/09 —Rough cut, then final cut 5 -1/2" casing. Install and test well head to 3000 psi. NU BOP, chg rams to 2 -7/8 ". Test rams. Install wear ring. Add 9.0 ppg brine to pits and filter. PU and run 4 -3/4" bit, csg scraper, and 81 jts of 2 -7/8" 6.5# J -55 tubing to 2514'. Circ and filter brine. 9/18/09 —Circ and filter brine to 10 microns. Weight up to 9.8 ppg, filter brine. POH. RU Schlumberger for CBL. Run CBL (SCMT) to 3422'. Log OOH and LD CBL tool. ND riser, NU shooting flange. 9 /19 /09— Finish NU shooting flange & lubricator. PU 1 perf gun and RIH to 500'. Test lubricator, flange, and casing to 1500 psi —OK. Finish RIH, correlate and perf Carya 2 -1 sand at 2345 -62'. POH & run perfs guns #2 - #5, perforating the Carya 2 -1 at 2260 -74' and the Beluga Tsuga sands at 2089 -99', 2058 -63', and 1810 -30' —gas at shaker —SI— CP to 25 psi, circ across top and monitor well. Rehead SLB line. Run #6— misfire. Found lose wire in firing head — repair. Rerun #6 —perf 1763 -68', runs #7 - #10 —perf 1752 -57', 1741 -63', 1658 -75'. 1414 -34'. 9/20/09—Continue perforating Belgua Tsuga sands: runs #11 - #16 —perf 1388- 1402', 1349 -54', 1208 -16', 1090- 1100', 1004 -12', & 920 -30'. RD SLB. ND shooting flange, NU riser and flow lines. RIH w/ 4 -3/4" bit and csg scraper to 2500'. CBU. Mix and pump high -vis (Barazan) sweep. POH and LD 13 jts tubing, scraper, and bit. PU 2 20' Stratapack screens w/ bull plug, 2 jts tubing, Weatherford mechanical -set packer, on -off tool, sliding sleeve, and RIH on 2 -7/8" tubing. Set packer at 2175' (on -off tool a 2173'). RU to swab. RU test unit. 9/21/09 —W.O. daylight to swab. Swabbed well in -5 runs, 500' increments —last FL at 1790' —rec 10+ BLW. Flow well off & on for 6 hours —final rate: 400 mcfpd at 130 psi. SI well -925 psi in 80 minutes. RU Pollard. Test lubricator to 1500 psi. Run PX plug to set in On -Off tool —new plug would not set. POH, get used plug from Pollard. RIH and set plug at 2174'. POH, PU prong, RIH and set in plug. Bleed tubing from 950 to 600 psi to test plug —held OK. POH w/ setting tool. PU and RIH w/ selective shifting tool. Open sliding sleeve at 2142' and let pressure equalize. Bleed off. POH. RD & release Pollard. Rev circ gas out. Release from on -off tool. POH. Scheduled BOP test waived by Chuck Scheave of AOGCC. 9/22/09— Finish POH, monitoring well. LD sliding sleeve. Pull wear ring. PU and run production string w/ 3 hydraulic packers and 5 sliding sleeves. Space out to land tubing. 3 0 • Reverse circ 33 bbl inhibited -brine packer fluid. Re- engage On -Off tool. Land tubing. Test tubing to 3000 psi and set hydraulic packers (at 1690', 1297', and 909' w/ sliding sleeves at 2014', 1701', 1619', 979', and 900' —all WXO except WXA at 900'). Test casing to 2000 psi. Set 2 -way check. ND BOP. NU tree. 9/23/09— Finish NU and test tree. RU to swab. W.O. day light. Swabbed to 890', rec 5 bbl brine. Lubricate BPV and set in hanger (all perfs behind closed siding sleeve or under PX plug). Replace R46 API ring gasket in tree w/ R45. Retest tree. Pulled BPV. Release rig and start demobilization. 9/24/09— Continue demob rig. RU test unit. RU Pollard. Open sliding sleeve at 979' — perfs at 920 -1216' flowed 285 mcfpd at 259 psi. SIP 324 psi in 35 minutes. Closed sleeve at 979'. Open sleeve at 1619'. Flow test perfs at 1349 -1675' after swabbing 8 bbl. Flowed 2 hr, built to 637 mcfpd at 442 psi. 1 hr SITP -564 psi. Closed sleeve at 1619'. Opened sleeves at 2014' and 1701' for test. 9/25/09— Continue demob rig while W.O. buildup from perfs at 1736- 2099'. Built to z 687 psi, then open to test unit, Recover 4.3 bbl water, then flowed to clean up. Built to rate of 2362 mcfpd at 562 psi. SI —FSIP -840 psi. Closed sleeves at 1701' and 2014'. Continue demob rig and equipment. 10/6/09 —RU Pollard. Test lubricator to 760 psi w/ well SIP. RIH and pull prong out of PX plug at 2174' — pressure inc to 780 psi. POH w/ prong. RIH and retrieve PX plug body. RIH w/ shifting tool and open sleeve at 2014' — pressure inc to 790 psi. Open sleeve at 1701'. POH. RD and release Pollard. Well built to 870 psig. Start 4 -point test thru test unit at 1335 hrs. Flow well to get the following rates: 949 mcfpd at 796 psia w/ 4.48 BWPD, 2073 mcfpd at 709 psia w/ 13.5 BWPD; 2593 mcfpd 638 psia w/ 5.05 BWPD; and 3143 mcfpd at 590 psia w/ 5.76 BWPD. C.A.O.F— � mcfpd. SI well for buildup at 2300 hrs. 10/7/09 -10.5 hr SITP -883 psia. RD &demobilize test unit. 10/14/09 to 11/12/09 —Start constructing production facilites and flowline to NCU 1 -2 -9 Production Facility. Installed heater /separator skid on NC11 pad and 150 bbl produced water tank. Built 4" Pipeline from NC 11 to NCU 129 Pad. Hydrotested pipeline to 2220 psig for 30 minutes. Pipeline placed 50ft off centerline of road and laid on surface awaiting permits to bury from DNR. 11/23/09 —RU Pollard. SITP -870 psig. Test lubricator with well pressure. 11/27/09 -- SITP -- . Open well to sales at rate of about 450 mcfpd. / Ed Jones 12/17/09 4 0 2 7/8 6.5# 8rd EUE J -55 — Aurora Gas, LLC %r .).1,'"4 Nicolai Creek #11 Final Actual Completion i s I - "r'. „ ., ` .4 13 -3/8" 68# K -55 Conductor September 2009 ` ' '' driven to 102' RKB- 16.Oft ,1 '. Drill 12 -1/4" Hole to 650' � w y Ow. s Beluga Tops p� ~ Tsuga 2.5-780' a „. . � . 9 -5/8" 36# K -55 Surface Casing set at Tsuga 2.61076' , e i 632' Tsuga 2.71298' y ) Cement w/ 13.0 ppg accelerated Type 1 Tsuga 2.81912' ' {', x7 Tyonek Tops , , v '' Carya 2 -1.1 2258' 1;l1r WXA Sliding Sleeve @ 900' Carya 2 -1.2 - 2344' II a y PHRP Hydraulic -Set Packer @ 909' 'I' }' ,,, WXO Sliding Sleeve @ 979' UPPER Tsuga 2.5 II COMPLETION: 920 -930' s % 1004 -1012' . r ` Tsuga 2.6 -1 1090 -1100' 1208 -1216' _ PHRP Hydraulic Set Packer @ " 1297' UPPER MIDDLE Tsuga 2 -7 1., ' COMPLETON: 1349-1355' - 1388 - 1402' P+ I fb ;ri 1414 -1434' "` ' 1658' -1675' FA§ ` ` WXO Sliding Sleeve @ 1619' IN •. ' — PIMP Hydraulic Set Packer @ 1690' LOWER MIDDLE Tsuga 2 -7 . +,., -- j COMPLETION: 1736' -1741' * CI Sleeve 1701' 1752 -1757' ' WXO Sliding @ 1763 -1768' Ds- 1810 -1830' Tsuga 2-8 ill EI: WXO Sliding Sleeve @ 2014' 2058 -2063' �-- 2089-2099' t,7, 4 Mechanical -set Packer @ 2175 w/ On- ' +. Off Tool @ 2173' w/ X Nipple 2 -7/8" tubing pup then crosses to 3 -1/2" s, 4,' With 2ea 3 -1/2" Stratapak screens @ I . 2234' with 2 -7/8" pup with bull plug in bottom. LOWER Carya 2 -1 - COMPLETION: 2260 -2274' Nit 56 2345 -2362' —+ T 5 `/2" 17# J -55 Casing to 3,589' MI) (TVD) } 0 Cement w/ 48 bbl 12.0 ppg + 95 bbl 14.8 ppg PBTD @ 3,509' Class `G' tail. Drill 7 -7/8" Hole to 3,600' A AURORA GAS, LLC RESERVES NICVLAi CREEK 411 VOLUMETRIC RGJ��v E PRVD INTERVAL Proposed NET PAY POROSTY Sw WF Omni Alt. POROSITY Calc Calc Z TEMP BHP OGIP RF REC GIP RESRVS PROB ML NuTech SWC XPT SWC in #1 Perfs ft % % SWC Net Pay % Rt Rw Sw deg R psia mcf /ac -ft % mcflac -ft 46 -48 ac RESRVS SHOW Perm Perm Mobility Prob MD /TVD NT NT NT Por, % ft den ohm -m % (measured values are bold) MMCF units and and mdlcp Prod LOWER COMPLETION Carya 2 -1.2 0.467 at 2345' 2345 2362 17 0 -- -- 24% 10 23% 14 0.340 47% 0.87 550 1110 436 90 392 188.323 65 nc 90 1.1 wtr Carya 2 -1.1 0.486 2260 2274 14 5 25.1 59.2 25.80% 25% 12 0.340 48% 0.87 550 1113 367 90 330 99.030 262 1.1 112 1.2 Wet (.55) b S /T= 1 287.3531 wtr LOWER MIDDLE COMPLETION Tsuga 2 -8 0.465 2089 2099 10 13 24.6 51.3 24.85 26% 22 0.632 47% 0.88 547 987 378 90 340 212.419 35 3 123 23 gas 2058 2063 5 3 24.3 45 27% 20 0.632 47% 0.88 547 972 416 90 374 53.874 55 2 III Tsuga 2 -7 0.479 0 -- -- 27.1 0 27% 11 0.736 69% 0.89 534 921 249 90 224 0.000 45 nc 180 1810 1830 20 2 21.3 40 20.8 16 23% 30 0.632 44% 0.89 547 882 357 90 321 246.423 231 1 25 1 1763 1768 5 3 24.6 35 21.6 27% 40 0.646 34% 0.89 545 881 447 90 402 57.956 90 3 13 0.35 1752 1757 5 2 27 51 29% 17 0.653 50% 0.89 544 876 368 90 332 31.827 40 4 1736 1741 5 4 24 38 19.1 28% 35 0.653 35% 0.89 544 877 415 90 374 71.715 154 5 4 0.12 tite S /T= 1 674.2151 UPPER MIDDLE COMPLETION 1658 1675 17 7 24.7 53 26.65 10 28% 20 0.653 47% 0.91 544 701 253 90 228 74.949 20 3 163 25.9 gas 1460 1468 0 -- -- 24% 15 0.788 67% 0.91 528 706 180 90 162 0.000 20 nc 1414 1434 20 15 25 36 23 27% 30 0.683 40% 0.92 540 684 339 90 305 215.084 70 13 46 0.5 1388 1402 14 12 21.7 27 23.35 32% 30 0.683 35% 0.92 540 671 329 85 280 157.934 147 2 80 5.06 Tsuga 2 -6 0.472 1349 1354 6 4 28 35 36% 100 0.691 18% 0.92 539 652 369 85 313 58.894 55 22 1320 1 25 31 10 24% 30 0.808 0.92 527 632 347 85 295 138.521 35 3 1291 0 -- -- 5 27% 18 0.812 0.925 526 618 228 85 194 0.000 45.636 • -- S/T= 1 506.861 UPPER COMPLETION 1208 1216 8 5 26 43 19.2 27% 25 0.699 45% 0.93 538 584 266 80 213 49.007 45 2 3 tite 0.471 1176 4 27.8 52 10 26% 20 0.828 0.93 525 563 237 80 190 87.193 10 4 1090 1100 10 2 25.5 47 4 23% 40 0.716 40% 0.935 536 527 219 80 175 16.104 10 nc Ts 2 -5 0.469 • 1060 1070 0 -- -- 5 28% 20 0.844 53% 0.935 523 512 211 80 168 38.735 15 nc 1004 1012 8 0 -- -- 5 24% 45 0.724 37% 0.94 535 493 228 80 183 42.016 20 nc 966 2 28 25% 25 0.831 52% 0.94 524 467 159 80 127 10 2 920 930 10 10 24.7 28 23.7 28% 100 0.683 21% 0.94 540 452 244 80 195 89.732 50 16 93 27.5 gas 893 900 0 -- -- 6 28% 25 0.870 48% 0.94 521 439 199 80 159 43.921 15 nc 842 860 0 -- -- 13 26% 30 0.850 46% 0.95 523 414 179 80 143 85.769 5 nc S /T= 196.859 Total Perfs 174 94 94 1665.287 439.775 MMCF 16 guns ASSUMPTIONS: Rw @120 1 0.45 in Beluga Sw =Sq Rt ((1/POR * *1.5 ) *(Rw /Rt)) 0.25 in Tyonek Ed Jones 9/16/2009 • 9 o -010 7 -- Au rora Gas, LLC www,aurorapower.com November 25, 2009 RECEIVED NOV 2 5 2009 Mr. Kevin Banks Alaska Gil & Gas Cons. Commission Acting Director Anchorage State of Alaska Department of Natural Resources Division of Oil and Gas 550 W. 7th Avenue, suite 1100 Anchorage, Alaska 99501 RE: Nicolai Creek #11 Production Accounting Code Revised Request from 11/16/09 Dear Mr. Banks: Aurora Gas, LLC ( "Aurora "), as Operator and 100% WI Owner of the Nicolai Creek Unit has successfully completed the drilling of the Nicolai Creek No. 11 ( "NC 11 ") natural gas development well, as well as completing the installation of the necessary facilities and gathering line to allow sustained production. Although the NC11 was included in the 2008/2009 Nicolai Creek Unit Plan of Development, it is not presently located within the Nicolai Creek Unit boundaries. Therefore, initial approval for sustained production is being requested on a lease only basis. Initially, Aurora intends to produce from the lower Tyonek Carya 2 -1 sands at the 2,260' to 2,362' perforated intervals. The lower Tyonek sands are isolated from the upper Beluga sands using sliding sleeves in the production tubing at the perforated intervals in the Beluga formation. Should it be necessary to produce from the upper Beluga sands, a retrievable plug will be set in the mechanical packer between the Beluga and Tyonek at 2,175', and the sliding sleeves will be reopened. Please refer to the attached wellbore diagram for clarification. Aurora will be applying for authorization from the Alaska Oil and Gas Conservation Commission ( "AOGCC ") to comingle the production from the Tyonek and Beluga within the NC 11 well bore, in accordance with 20 AAC 25.215. Based on production test results and an analysis performed by Aurora's engineer, Mr. J. Edward Jones, on the estimated recoverable reserves, the allocation of production would be approximately 28% Tyonek and 72% Beluga. Please refer to the attached production test spreadsheets. Therefore, Aurora requests the necessary approval to allow sustained production from ADL 391472, and allocation codes for production accounting purposes for both the Beluga and Tyonek pools. It is Aurora's intention to pursue the expansion of the Nicolai Creek Unit boundary to include the productive area within ADL 391472, and the establishment of a new Participating Area. Initial production will assist in evaluating the reservoir pressures and the aerial extent of the NC 11 reservoir(s). 1400 West Benson Blvd., Suite 410 • Anchorage, AK 99503 • (907) 277 -1003 • Fax: (907) 277 -1006 6051 North Course Drive, Suite 200 • Houston, TX 77072 • (713) 977 -5799 • Fax: (713) 977 -1347 • • Kevin Banks, Acting Director NC 11 Production Accounting Code Request November 25, 2009 Page 2 As indicated earlier, the NCI 1 well is located on State Oil and Gas Lease ADL- 391472. Aurora is the 100% WI owner of this lease. The well was drilled to a vertical measured depth of 3,600' and was plugged back to 3,509'. The well was a straight -hole, having the surface and bottom -hole locations at: T. 11 N., R. 12 W., S.M. Section 30, 1,534' from east line, 1,894' from south line, Thank you for your time and consideration. Please let me know if you need additional information. Sincerely, Bruce D. Webb Manager, Land and Regulatory Affairs Cc: Temple Davidson, ADNR Jim Stouffer, ADNR Brian Havelock, ADNR w As€€0 • 2 7/8 6.5# 8rd EUE J -55 Aurora Gas, LLC �, -.. ` I - ; . >f,' , ' ` '' Nicolai Creek #11 Final Actual Completion ��' a " . ` " 13-3/8" 68# K -55 Conductor September 2009 .} , th "' driven to 102' RKB — 16.Oft -" Drill 12 -1/4" Hole to 650' ' Beluga Tops Tsuga 2.5 . 9 -5/8" 36# K -55 Surface Casing set at Tsuga 2.6 632' Tsuga 2.7 4 Cement w/ 13.0 ppg accelerated Type 1 Tsuga 2.8 Tyonek Tops .y Carya 2 -1.1 / � 4 WXA Sliding Sleeve @ 900' Carya 2 -1.2 -- ' " PHRP Hydraulic -Set Packer @ 909' i III a�w WXO Sliding Sleeve @ 979' Tsuga 2.5 920 -930' .••— 1004 -1012' . t Tsuga 2.6 1090 -1100' 1208 -1216' -; ' PHRP Hydraulic Set Packer @ — 1297' Tsuga 2-6 1.."..:.,:. 1349 -1355' Tsuga 2 -7 *' W 1388 - 1402' ` "` $�,i 1414 -1434' ,. A trI lt„? WXO Sliding Sleeve @ 1619' 1658' -1675' ,. `., -- ; PHRP Hydraulic Set Packer @ 1690' • Tsuga 2 -7 4 ' - - -- t 1736' -1741' .. l IY i p WXO Sliding Sleeve @ 1701' 1752 -1757' 1763 -1768' Mgr row. -. 1810 -1830' Tsuga 2-8 _ .I. WXO Sliding Sleeve @ 2014' 2058 -2063' } 2089 -2099' Mechanical -set Packer @ 2175 w/ On- Off Tool @ 2173' w/ X Nipple 11 2 -7/8" tubing pup then crosses to 3 -1/2" am With 2ea 3-1/2" Stratapak screens @ • 2234' with 2 -7/8" pup with bull plug in bottom. Carya 2 -1 2260 -2274' O 2345-2362' If 5 'A" 17# J -55 Casing to 3,589' MD (TVD) Cement w/ 48 bbl 12.0 ppg + 95 bbl 14.8 ppg PBTD @ 3,509' Class 'G' tail. Drill 7 -7/8" Hole to 3,600' AURORA GAS, LLC NICOLAI CREEK UNIT #11 TEST RESULTS SUMMARY 2009 INITIAL COMPLETION ISITP, psi DATE DATUM TEST MCFPD FTP ICalc BHP WTR COMMENTS of TOP BASE NET (mid perf) NO. (Calc psia) TEST MD/TVD MD/TVD PERFS TVDss (tester) psig XPT, psia BPH TSUGA 2 -5 AND UPPER 2 -6- -Upper Completion 9/24/2009 920 930 10 2 . FL at 880' after opening sleeve. 1004 1012 8 (JB) 324 1090 1100 10 -1048 285 258 334 4.20 5.2 bbl load water 1208 1216 8 (347 psia) of 8.4 bbl: 1.7 BPH • 0 XPT= 452 Water in tubing - -FL at 780' - -BHP -452 psig 36 Lower TSUGA 2-6 and Upper TSUGA 2- 7- -Upper Middle Completion FL at 780' after opening sleeve 9/24/2009 1349 1354 5 3 637 442 564 1.28 unloaded 8.4 BW prior to test - -calc load= 1388 1402 14 (JB) 583 10.6 bbl max - -10.6 bbl total recovery 1414 1434 20 -1492 (598 psia) +47 psi for FL 1658 1675 17 XPT= 709 56 Lower TSUGA 2 -7 and TSUGA 2 -8- -Lower Middle Completion FL at 1420' after opening sleeves. 9/25/2009 1736 1741 5 4 2362 562 830 0.93 unloaded 3.9 bbl before test - -calc load= 1752 1757 5 (JB) 867 9.7 bbl max - -8.1 total recovery 1 1763 1768 5 (882 psia) 1810 1830 20 - 1897.5 XPT= 915 2058 2063 5 2089 2099 10 • 50 CARYA 2 -1.1 AND 2 -1.2 -Lower Completion 950 0.00 9/21/2009 2260 2274 14 1 403 130 1001 Swabbed 10.25 bbl before flowing - -calc load 2345 2362 17 -2291 (EJ) (1016 psia) 11.7 bbl in tbg + 2.1 to btm of top perfs 31 XPT= I 1112 I Small amt in test sep. 1 TOTAL 3686 MCFPD Ed Jones 9/28/2009 AURORA GAS, LLC NICOLAI CREEK #11 VOLUMETRIC RESERVES PRVD INTERVAL Proposed NET PAY POROSTY Sw WF Omni Alt. POROSITY Calc Calc Z TEMP BHP OGIP RF REC GIP RESRVS PROB ML NuTech SWC XPT SWC in #1 Perfs ft % % SWC Net Pay % Rt Rw Sw deg R psia mcf /ac -ft % mcf /ac -ft 60 ac RESRVS SHOW Perm Perm Mobility Prob MD /TVD NT NT NT Por, % ft den ohm -m % (measured values are bold) MMCF units and and and /cp Prod LOWER COMPLETION Carya 2 -1.2 0.467 at 2345' 2345 2362 17 0 -- -- 24% 10 23% 14 0.340 47% 0.87 550 1110 436 90 392 235.404 65 nc 90 1.1 wtr Carya 2 -1.1 0.486 2260 2274 14 5 25.1 25.80% 25% 12 0.340 48% 0.87 550 1113 367 90 330 99.030 262 1.1 112 1.2 Wet (.55) b S /T= 1 334.4331 wtr LOWER MIDDLE COMPLETION Tsuga 2 -8 0.465 2089 2099 10 13 24.6 51.3 24.85 26% 22 0.632 47% 0.88 547 987 378 90 340 265.524 35 3 123 23 gas 2058 2063 5 3 24.3 45 27% 20 0.632 47% 0.88 547 972 416 90 374 67.343 55 2 • Tsuga 2 -7 0.479 0 -- -- 27.1 0 27% 11 0.736 0.89 534 921 249 90 224 0.000 45 nc 180 wtr 1810 1830 20 2 21.3 40 20.8 16 23% 30 0.632 44% 0.89 547 882 357 90 321 308.028 231 1 25 1 wtr 1763 1768 5 3 24.6 35 21.6 27% 40 0.646 34% 0.89 545 881 447 90 402 72.445 90 3 13 0.35 wtr 1752 1757 5 2 27 51 29% 17 0.653 50% 0.89 544 876 368 90 332 39.784 40 4 1736 1741 5 4 24 38 19.1 28% 35 0.653 35% 0.89 544 877 415 90 374 89.644 154 5 4 0.12 tite S /T= 1 842.7681 UPPER MIDDLE COMPLETION 1658 1675 17 7 24.7 53 26.65 10 28% 20 0.653 47% 0.91 544 701 253 90 228 95.680 20 3 163 25.9 gas 1460 0 -- -- 24% 15 0.788 67% 0.91 528 706 180 90 162 0.000 20 nc 1414 1434 20 15 25 36 23 27% 30 0.683 40% 0.92 540 684 339 90 305 274.575 70 13 46 0.5 1388 1402 14 12 21.7 27 23.35 32% 30 0.683 35% 0.92 540 671 329 85 280 201.618 147 2 80 5.06 Tsuga 2 -6 0.472 1349 1354 6 4 28 35 36% 100 0.691 18% 0.92 539 652 369 85 313 75.184 55 22 1308 1 25 31 10 24% 30 0.808 48% 0.92 527 632 347 85 295 176.835 35 3 1278 1291 0 -- -- 5 27% 18 0.812 57% 0.925 526 618 228 85 194 0.000 58.259 -- S /T= I 647.0571 UPPER COMPLETION 1208 1216 8 5 26 43 19.2 27% 25 0.699 45% 0.93 538 584 266 80 213 63.922 45 2 3 tite 0.471 1164 1176 4 27.8 52 10 26% 20 0.828 56% 0.93 525 563 237 80 190 113.730 10 4 1090 1100 10 2 25.5 47 4 23% 40 0.716 40% 0.935 536 527 219 80 175 21.005 10 nc Ts 2 -5 0.469 • 1060 1070 0 -- -- 5 28% 20 0.844 53% 0.935 523 512 211 80 168 50.524 15 nc 1004 1012 8 0 -- -- 5 24% 45 0.724 37% 0.94 535 493 228 80 183 54.804 20 nc 950 966 2 28 25% 25 0.831 52% 0.94 524 467 159 80 127 10 2 920 930 10 10 24.7 28 23.7 28% 100 0.683 21% 0.94 540 452 244 80 195 117.042 50 16 93 27.5 gas 893 900 0 -- -- 6 28% 25 0.870 48% 0.94 521 439 199 80 159 57.288 15 nc 842 860 0 -- -- 13 26% 30 0.850 46% 0.95 523 414 179 80 143 111.873 5 nc SIT= 256.773 Total Perfs 174 94 94 2081.031 568.509 MMCF 16 guns ASSUMPTIONS: Rw @120 i 0.45 in Beluga Sw =Sq Rt ((1/POR * *1.5 ) *(Rw /Rt)) 0.25 in Tyonek Ed Jones 9/16/2009 • 4 Mahnken, Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, October 07, 2009 8:19 AM To: Mahnken, Christine R (DOA) Subject: FW: NC 11 Test Summary.xls Christine, Please print this email and place it in well file 2090670. Thanks, Steve D. Original Message From: Aubert, Winton G (DOA) Sent: Monday, September 28, 2009 2:29 PM To: 'Bruce D Webb' Cc: Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: NC 11 Test Summary.xls Bruce, Based upon information submitted with the attached E -mail, AOGCC hereby approves commingling production from the Tyonek Tsuga 2 -7/2 -8 and Beluga Carya 2- 1.1/2 -1.2 zones in well Nicolai Creek 11 (PTD 209 -067), for evaluation (well test) purposes. This approval does not extend to regular production from Nicolai Creek 11. Winton Aubert AOGCC 793 -1231 Original Message From: Bruce D Webb [mailto:bwebb @aurorapower.com] Sent: Monday, September 28, 2009 1:56 PM To: Maunder, Thomas E (DOA); Aubert, Winton G (DOA); Davies, Stephen F (DOA) Subject: FW: NC 11 Test Summary.xls Tom, Winton and Steve, The NC #11 looks to be a good well. Ed wants to verify that we can produce from the Tyonek Tsuga 2 -7/2 -8 and Beluga Carya 2- 1.1/2 -1.2 perforations simultaneously. The C #11 is outside the existing Unit PA boundaries, which we plan on either expanding or creating a new PA. -Bruce Original Message From: Ed Jones [ mailto:jejones @aurorapower.com] Sent: Monday, September 28, 2009 12:10 PM To: 'G Scott Pfoff'; 'Mike Flaherty'; 'Chad Helgeson' Cc: 'Johann Bartels'; 'JON ROBERTA WEST'; 'Dave Boelens'; 'Bruce D Webb' Subject: NC 11 Test Summary.xls Attached is the test summary from NC 11- -total of 3.6 MMCFPD from the 4 completions, with 2.4 MMCFPD coming from the 2nd Lower. I think that all the zones were still cleaning up, so rates should be a bit higher. From these tests, it looks like commingling the two lower completions may be the best initial production plan. Thus, we'll plan to get Pollard out some time soon, pull the plug in the deepest packer and open the two deepest sliding sleeves, then do a combined 4 -point test of these 2 completions. Bruce, please confirm that there will be no problem commingling these zones (2nd Lower Completion Beluga Tsuga and Lower Completion Upper Tyonek). Thanks, Ed 1 • Aurrora Gas, LLC www aurorap®wer. Mr. Howard Oakland October 1, 2009 Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 RE: Nicolai Creek #11 Dear Mr. Oakland: This letter in duplicate originals transmits the data to you identified below, pursuant to Aurora Gas, LLC's obligation to you. This data is relative to operations at the Nicolai Creek Undefined Gas Field, Cook Inlet, Alaska. The enclosed data consists of the following: SCHLUMBERGER PAPER LOGS & CD Platform Express, AIT /RHOZ/NPOR/PEFZ/HCAL /GR/SP Core Sample Taker, CST - GR Express Pressure Tool, XPT — GR FMI Dipmeter, Dip Meter — GR SCHLUMBERGER REPORT & CD PressureXpress, Data Evaluation Report HORIZON LOGS Oil and Gas MD Mud Log, 1:600 scale Oil and Gas MD Mud Log, 1:240 scale Please signify that you have received and accepted this data by signing in the space below and returning this letter to me at the Anchorage address below or by fax to me at 907 - 277 -1006. If you have questions, please contact me, or Ed Jones at the Houston number below. Sincerely, ' r Bruce D. Webb Manager, Land and Regulatory Affairs RECEIVED AND ACCEPTED ABOVE DATA — 6lo'4 11 ado This r tray, of , 2009. B 0 �_�� 9. �� �7) i `7- ✓' .3 < � '� - � -1 �. .- je'1�s', �:7 „J,'� ��:, :�' j��� ��`� gip.; .`..� _ a a.�s .. 30Z 5.4%,=3L 'CL:L e Dr:',/m` J -9 .+° C:if;'� ...i 77J72 � ��.vJ S7g'- 57:�? , �_- ="a ;;,' :(,.:13) D77- _ -137 • . Aurfora Gas ' LLC www.aurorapower.com September 17, 2009 Mr. Howard Oakland Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 RE: Nicolai Creek #11 API 50- 283 - 20135 -00 PTD #209 -067 Dear Mr. Oakland: This letter in duplicate originals transmits the material(s) identified below, pursuant to Aurora Gas, LLC's obligation to you. This material is relative to operations at the Nicolai Creek Unit South Undefined Gas Field, Cook Inlet, Alaska. Enclosed herewith: HORIZON WELL LOG SERVICE Nicolai Creek #11 Drill Cutting Samples ( 3 1- set, consisting of 3 boxes K� 110' MD to 3,600' MD Please signify that you have received and accepted this data by signing in the space below and returning this letter to me at the Anchorage address below or by fax to me at 907 -277 -1006. If you have questions, please contact me, or Ed Jones at the Houston number below. Sincerely, 4r c‘ Oastus- Bruce D. Webb Manager, Land and Regulatory Affairs RECEIVE ► ND ACCEPTED ABOVE DATA This day of , 2009. 1400 West Benson Blvd., Suite 410 • Anchorage, AK 99503 • (907) 277 -1003 • Fax: (907) 277 -1006 6051 North Course Drive, Suite 200 • Houston, TX 77072 • (713) 977 -5799 • Fax: (713) 977 -1347 aeq• • • 8, ,,,,, s ci sn oar , iii SEAN PARNELL, GOVERNOR Li ,,, / �T�+ tt ALASKA OIL AND `=A`7 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION 1 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 ✓ FAX (907) 276 -7542 Mr. Bruce D. Webb Manager, Land and Regulatory Affairs Aurora Gas, LLC 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Nicolai Creek, Beluga Undefined Gas Pool, Nicolai Creek South, Undefined Gas Pool, Nicolai Creek #11 Aurora Gas, LLC Permit No: 209 -067 Surface Location: 1534' FEL, 1894' FSL, T11N, R12W, S.M., Section 30 Bottomhole Location: 1534' FEL, 1894' FSL, Ti 1N, R12W, S.M., Section 30 Dear Mr. Webb: I Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Aurora Gas, LLC assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, j 11 � D aniel T 'S' = ount, Jr. q Chair DATED this 1 day of August, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • II 1J LTJ ' S EAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99.11 -3539 PHONE (907) 279 -143. FAX (907) 276 -7.42 Mr. Bruce D. Webb Manager, Land and Regulatory Affairs Aurora Gas, LLC 1400 W. Benson Blvd., Suite 410 c.- Anchorage, AK 99503 C \ A p Re: Nicolai Creek, Beluga Undefined Gas Pool, Nicolai Creek South, Undefined Gas Pool, Ni olai eek #11 Aurora Gas, LLC Permit No: 209 -067 Surface Location: 1534' FEL, 1894' FSI,,i� 1 , R12W, S.M., Section 30 Bottomhole Location: 1534' FEL, 1894' FS , T11N, R12W, S.M., Section 30 Dear Mr. Webb: /V- D Enclosed is the approved application sr permit to drill the above referenced development well. This permit to drill does not exem• you from obtaining additional permits or an approval required by law from oth: governmental agencies and does not authorize conducting drilling operations u it all other required permits and approvals have been issued. In addition, the Co mission reserves the right to withdraw the permit in the event it was erroneously iss , ed. Operations must be conduct: 'd in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrati e Code unless the Commission specifically authorizes a variance. Failure to co ply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alask. Administrative Code, or a Commission order, or the terms and conditions of this p- it may result in the revocation or suspension of the permit. When providing notice or a representative of the Commission to witness any required test, contact the Com ission's petroleum field inspector at (907) 659 -3607 (pager). / Sincerely, Daniel T. Seamount, Jr. 1-II Chair DATED thi day of August, 2009 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. u rrora Gas, www.aurorapower.com • June 10, 2009 RECEIVED Mr. Dan Seamount, Chair 1 u 2009 Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 .Alaska Oil &G as C. Commission Anchorage ons Anchorage, Alaska 99501 RE: Application for Permit to Drill: Nicolai Creek No. 11 Dear Mr. Seamount: Aurora Gas, LLC hereby applies for a Permit to Drill an onshore gas exploration well in the Nicolai Creek Field south of the village of Tyonek. The well is planned as a vertical well targeting the Upper Tyonek Formation to test for gas. Please refer to the attached Drilling Plan. The rig to be used is the AWS #1. The rig's well control systems are on file with the Commission. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill. 2) A plat showing the surface location of the well. 3) A Time versus Depth plot. 4) Proposed casing program. 5) Proposed cementing program. 6) Proposed drilling fluid program. 7) Proposed summary drilling program. 8) Summary of Drilling Hazards. 9) Schematic of the proposed welibore and completion. 10) Aurora Gas does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. 11) The following are Aurora Gas' designated contacts for reporting responsibilities to the Commission: 1400 West Benson Blvd., Suite 410 • Anchorage, AK 99503 • (907) 277 -1003 • Fax: (907) 277 -1006 6051 North Course Drive, Suite 200 • Houston, TX 77072 • (713) 977 -5799 • Fax: (713) 977 -1347 411 • Mr. Dan Seamount June 10, 2009 Page 2 1) Completion Report Ed Jones, Executive Vice President (20 AAC 25.070) (713) 977 -5799 2) Geologic Data and Logs Andy Clifford, VP - Exploration (20 AAC 25.071) (713) 977 -5799 Aurora submitted a Spacing Exception application on September 17, 2007. If you have any questions or require additional information, please contact me or Mr. Ed Jones at (907) 277 -1 003. Sincerely, AURORA GAS, LLC Bruce D. Webb Manager, Land and Regulatory Affairs enclosures • Office 110 Project 29 June 2009 INPUT OUTPUT Geographic, NAD83 State Plane, NAD27 5004 - Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. Nicolai Creek 11 1/1 Latitude: 61 00 45.341 NorthinglY: 2565170.418 Longitude: 151 28 07.952 Easting/X: 239785.483 Convergence: -1 16 58.70838 Scale Factor: 0.999977046 Datum Shift (m.): Delta Lat. = 62.396, Delta Lon = - 121.346 ti Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers I z 3 i 'N 11 11 .a - b I 1 i A il; i ; II k 1 a ! A i 1 1 E a 11 - 1 1 a1 11�� 1 o g 1 i'1 i 1 i l l A $ psi : _ .. gi 1 q « x 1 ?-. gA 1 , ih 1 h h I :q q 1 1 ! S 1 $11 illg11$ itt« l 8i a tA► 1 11 \''.` t il g IN ,,` II „,.,,,,,:„,,, � I Q :.:: '',‘',.....,‘:\s‘:‘:',\I'x':'::',:,:‘,‘::::,:.N:':::ss::::::,:,:::::,,:::;s:r:f., 1— _ I i ',,w,::::::::::::::::,:::::,::::,:::,y,:s:::,:,:,:s::.:,::::::.:•:::::::,:,,,,:s,:::,: I i o I I m_ 1 �i ` ` t; \'' s- .1.- — , . 11 o jj t; s U `: ;' P .s W ,;; 1 / Iiil e - s':':::::::::::`,`,`,',`,'Y;`::::::;::::.`,:.`,`,`S:::`,:.`,:::‘:‘`.:::.V:‘:s%\1:: A F �.. ""® Lam'_`_. E a a $ ©� � !, g ....prim \ I .iig i 1 2 ipli ill 2 i 1 � 2 ; Ii4o illiill - I • • STATE OF ALASKA � � oo � ALASWOIL AND GAS CONSERVATION COM ION JUN 1 0 2000 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Aurora Gas, LLC Bond No. NZS 429815 * �4 � Nicolai Creek #11 3. Address: 6. Proposed Depth: �L t /. > 12. Feld /Pool(s): 6. 1400 W. Benson Blvd, Suite 410, Anchorage AK, 99503 MD: ,, TVD: O f Zl 0 1 6 g (IP, /46 s 4a. Location of Well (Governmental Section): 7. Property Designation (, Nicolai Creek U Surface: T. 11 N., R.,12 W., S.M., Section 30 AA -8426 4,/(e 4 C 4 lam - ' 644 f" 1,53C and 1,894' FSL 8. Land Use Permit: 13. Approximate Spud Dat Top of Productive Horizo ,/j X1,2 0' none 8/1/2009 7 .54 , 1 Total Depth: 3,400' TVD /MD 9. Acres in Property: 14. Dist. to Nearest Property: X•� z j7 ' 5 Y- 2 5C 677ta. 5f5 A 4 L/ 640 1,534' FEL and 1,894' FSL 4b. Surface Location of Well (State Base Plane Coordinates): nJ /QP Z7 10. KB Elevation 20' MLLW 15. Distance to Nearest Well x- 2_5.649347. 15 y- 1„9809:804 zone: 4 (Height above GL): 16' feet Within Pool: 1,525' 16. Deviated wells: Kickoff depth: feet 17. Maximum Anticipated Pressures in psig (see 20 25.035) Maximum Hole Angle: degrees Downhole: 1,730 psi Surface: , ,5 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom �¢ment Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 13 -3/8" 68# K -55 BW 80' 16' 16' 95' 95' N/A 12-1/4" 9-5/8" 53.5/40# L- 80/K -55 BTC 635' 16' 16' 650' 650' 220 sx 7 -7/8" 5 -1/2" 15.5/17# K- 55/N -80 BTC 3,385' 16' 16' 3,400' 3,400' 466 sx 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch SI Drilling Program 0 Time v. Depth Plots Shallow Hazard Analysis 0 Revised Property Plat 0 Diverter Sketch 0 Seabed Report❑ Drilling Fluid Program0 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Bruce D. Webb Title Manager, Land and Regulatory Affairs Signature c--7._ °. ) LAje.,:,,.6 Phone (907) 277 -1003 Date June 10, 2009 Commission Use Only Permit to Drill API Number: _ , _ n Permit Aggro yo See cover letter for other Number: � 7 50 -1 ' 7t S " (--' h Date: 5 requirements. Conditions of approval: If box checked, well may not to explore for, test, or produce coa hane, ga hydrates, or gas contained in shat s: ❑ Other: Samples req'd: Yes❑ No y,� Mud log req'd: Yes N o [I] 1 H measures: Yes❑ No l� Directional svy req'd: Yes ❑ No ❑ L i 20 4Ac Z5.os5 (k)(z) cLi�le ✓Te,r Ve,.�f Ii �ta r'S a� T2 sk r Awe 130 P E fo 3000 f TA: . 'rest as.vt_u.(av EoPE fo is pFc' . (5 7 , :/ 3 7 2 APPROVED BY THE COMMISSION DATE � , COMMISSIONER Form 10-401 Revised 12/2005 ( J N A L 1 J 1 i Submit in Du ly� 51.61 • • 7 8 9 10 NORTH SCALE 0 1 MILE 2 MILE I 18 17 16 15 FEET CONSTRUCTION NOTES ER LIN 1. ;r, 1) PROJECT INCLUDES THE CONSTRUCTION 19 20 21 - " P O 22 1240 L.F. OF ACCESS ROAD (UPLANDS) AND THE ,l CONSTRUCTION OF A 160 FT. X 265 FT. PIPELINE _ - - " -- - - - -- DRILLING PAD (FOOTPRINT, WETLANDS). -- " -- _ -k -- PO /NT 2) FOOTRINT AREA IMPACTED BY PROPOSED 5, TANK FARM DRILLING PAD EQUALS 42,400 SQUARE FEET. '�` 30 29 k W 28 27 A NIKOLAI 3) FOOTRINT AREA OF THE PROPOSED UPLANDS SREEKIII, �.� _" __._ ACCESS ROAD CONSTRUCTION EQUALS AIRSTRIP SH /RLEYV'LLE 28,374 SQUARE FEET. 711 /5 PROJECT 4) ESTIMATED GRAVEL FILL REQUIRED FOR PAD CONSTRUCTION IMPACTING THE WETLANDS COOK / N L E T EQUALS 4,711 CUBIC YARDS. 5) ESTIMATED GRAVEL FILL REQUIRED FOR N UPLANDS ROAD CONSTRUCTION EQUALS OC T11N 1,653 CUBIC YARDS. USGS QUAD. TYONEK A4 SURVEY NOTES 1) BASIS OF COORDINATES IS ALASKA STATE PLANE NAD 83 ZONE 4 DETERMINED FROM ' 4" ' ':;,, A k (::. AN OPUS SaUTION ON BM1 GPTF. 2) ELEVATION DATUM NAVD88 BASED ON THE ! n OPUS SOLUTION ALL ELEVATIONS SHOWN HEREON WERE TAKEN ON GROUND. 3) SECTION LINES SHOWN HEREON ARE BASED ON PROTRACTED VALUES. PROJECT LOCATION REVISION: _ NICOLAI CREEK NO. 11 SECTION 30, T11N, R12, S.M., AK DATE: 4/28/09 MCLANE CONSULTING INC. C. t C► DRAWN BY: MSM PURPOSE SCALE: 1" =5280' ENGINEERING O BOX 468 SOLDOTNA, AK. 99689 PING ROAD AND PAD CONSTRUCTION PROJECT NO. 093020 VOICE: (907) 283 -4218 FAX: (907) 283-3265 VW W V.MCLANECG.COM BOOK NO. 04-20 APPLICANTS AURORA GAS, LLC SHEET w Aurora LLC 140WEST ST° E BLVD. SUITE 410 ANCHORAGE, AK 99503 1 OF 4 • 0 SCALE 0 300 600 I 1 __ FEET I NORTH ACCESS ROAD LINE TABLE r•r --- LINE LENGTH BEARING _e_ L1 150.99 S85 °24'32 "E L2 127.62 N85 °19'02 "E L3 125.48 S87 °47'45 "E L4 134.71 N87 °04'44 "E . L5 247.07 N85 °56'45 "E ADL 36736 L6 201.93 N87 °43'21 "E L7 250.67 N89 °26'06 "E CREEK �� EXISTING PAD WETLANDS DRILLING PAD 160' x 265' 15' WIDE ACCESS ROAD 265 0 c, 1 1 ---- - " - ;o, I L L3 L2 L1 n '' © L6 L5 - - rL7==- -___ -- _ ---- . - - -_- o APPROX. MHTW Q BEGIN PROJECT CA Co o N: 2564901.510 NICOLAI CREEK NO. 11 E:1381226.621 N: 2564934.415 o LAT: 61 °00'45.329 "N E:1379809.804 z LONG:151 °27'39.200 "W LAT: 6100'45.341' N cn LONG:151 °28'07.952 "W w ELEV. 20' NAVD88 ° o z w SEC. 30 • CO T11N, R12W S.M. AK • • U Ww U) to PROJECT REVISION: _ NICOLAI CREEK NO. 11 LOCATION SECTION 30, T11 N, R12, S.M., AK DATE: 4/28!09 /, MCLANE CON SULTING INC. PURPOSE SCALE B 1 " =3 00 ' LE: i00 ENGINEERING TESTING SUR - MA ICE (907) 884218 FAX: ROAD AND PAD CONSTRUCTION PROJECT NO. 093020 VOICE: (907) 2834218 FAX: (907) 2813285 W W W.MCLANECG.COM BOOK NO 04 -20 APPLICANTS AURORA GAS, LLC SHEET I� A urtiorra Gas LLC L C CHAD HELSO L VD SUITE 410 ANCHORAGE, AK 99503 OF 4 ATTN • . CONTAINMENT BERMS 2' HEIGHT, 2:1 SLOPES 1 - L WETLANDS WETLANDS 36" (MINIMUM) SELECT MATERIAL EXISTING GROUND TYPE A IN FILL AREAS NOTES: 1. ALL WASTE EXCAVATION SHALL BE PLACED IN DESIGNATED STORAGE BERMS OR REMOVED AND PLACED IN A CONTRACTOR SUPPLIED DISPOSAL SITE. 2. GRAVEL FILL SHALL BE PLACED IN NO GREATER THAN 8" LIFTS AND COMPACTED TO 95% OF MAXIMUM DENSITY, AS DETERMINED BY THE ENGINEER. 3. TOP 4" SELECT MATERIAL TYPE A SHALL BE COBBLE FREE (3" MINUS). 4. SELECTED MATERIAL TYPE A SHALL BE UNDERLAIN WITH GEOTEXTILE, AMOCO 2002 OR EQUIVALENT. 5. EXISTING GROUND VARIES THROUGHOUT PROPOSED PAD. 6. BORROW FILL WILL BE MEASURED IN PLACE, FULLY COMPACTED, UTILIZING BEFORE CROSS SECTION SURVEYS AND DESIGN TEMPLATE CROSS SECTIONS. 0 3 A TYPICAL EXPLORATION PAD FINISH GRADE SECTION SCALE: 1 "= 50' 4' 2% 15' / f- 2% - -f 24" MIN. SELECT �5 MATERIAL TYPE A WETLANDS EXISTING TRAIL N Sr EXISTING GROUND BEACH NOTES: 1. ALL WASTE EXCAVATION SHALL BE PLACED IN DESIGNATED STORAGE BERMS OR REMOVED AND PLACED IN A CONTRACTOR SUPPLIED DISPOSAL SITE. 2. GRAVEL FILL SHALL BE PLACED IN NO GREATER THAN 8" LIFTS AND COMPACTED TO 95% OF MAXIMUM DENSITY, AS DETERMINED BY THE ENGINEER. 3. TOP 4" SELECTED MATERIAL TYPE SELECT A SHALL BE COBBLE FREE (3" MINUS). 4. SELECTED MATERIAL TYPE A SHALL BE UNDERLAIN WITH GEOTEXTILE, AMOCO 2002 OR EQUIVALENT. 5. IN WETLAND AREAS GEOGRID MAY BE USED TO HELP STABILIZE GRAVEL FILL AS DETERMINED BY THE ENGINEER. 6. EXISTING GROUND VARIES THROUGHOUT PROPOSED ROAD ALIGNMENT. 7. IN WETLAND AREAS CONTRACTOR MAY NOT PLACE FILL, REMOVE NATIVE MATERIAL, OR RUN EQUIPMENT OUTSIDE DESIGNATED CONSTRUCTION ZONE AS MARKED IN FIELD BY THE ENGINEER. 8. ROAD SURFACE FILL WIDTH VARIES DEPENDING ON LOCATION. 0 TYPICAL ACCESS ROAD SECTION - WETLANDS SCALE: 1 " =5' PROJECT LOCATION REVISION: _ NICULAI CREEK NO. 11 SECTION 30, T11 N, R12, S.M., AK DATE: 4 /28/09 MCLANE CONSULTING INC. DRAWN BY: MSM PURPOSE ROAD AND PAD CONSTRUCTION SCALE: 1".5075 ENGINEERING - TESTING - SURVEYING - MAPPING VOICE: ( 907) 283 -422 8 FAX: (907) 2833265 TYPICAL SECTIONS PROJECT NO. 093020 W W W.MCLANECG.COM BOOK NO. 04-20 9 r APPLICANTS AURORA GAS, LLC SET urora Gas, L.L BENSON HELGESON BLVD. SUITE 410 ANCHORAGE, AK 99503 3 OF 4 ATTN. CHAD • 0 N NICOLAI oc CREEK UNIT 19 20 21 30 NCU WELL 11 SURFACE LOCATION 29 N= 2564934.415 28 E= 1379809.804 TRACT 2 ii, AA 8426 ,� 1966 MEAN HIGH WATER LINE 7 -------- PER ADL 36736 TRA TRACT 2 CT 3 ADL 17598 ADL 17585 SOUTHERN PA BOUNDARY NICOLAI CREEK UNIT 33 —.1411I TRADING BAY 31 32 NORTH COOK INLET '`'"` SCALE 0 2000 4000 I 1 1 FEET T11 N PROJECT NICOLA! CREEK NO. 11 LOCATION REVISION _ SECTION 30, T11N, R12, S.M., AK DATE: 4/28/09 MCLANE CONSULTING INC. DRAWN BY: MSM PURPOSE SCALE 1 ENGINEERING - TESTING - SURVEYING - MAPPING P.O. BOX 468 42/8 FAX: AK. 99869 UNIT BOUNDARIES PROJECT NO. 093020 VOICE: (907) 283 -4218 X: (907) 283 -3265 VWVVVINCLANECG COM BOOK NO. 04-20 APPLICANTS AURORA GAS, LLC SHEET . A urrora Gas, L L 1400 Vl£ST BENSON BLVD SUITE 410 ANCHORAGE, AK 99503 4 OF 4 ATTN. CHAD HELGESON T Aurora Gas, LLC Iicoiai Creek #11 Drilling Plan NICOLAI CREEK #11 Nicolai Creek #11 is a grass -roots well targeting Beluga and Tyonek Gas Production. It is located in the Nicolai Creek Gas Field, drilled from a new pad about 1800' west of the Nicolai Creek Unit #1B, #2, and #9 wells and facility. It will target Beluga Tsuga 2 -6 to the Upper Tyonek Carya 2 -4 sands that have produced/are producing in the Nicolai #1B, 2, and 9 wells. Pre Rig work 1. The site for the Nicolai Creek #11 is an old staging area about 1/3 mile west of the existing Nicolai Creek Unit 1 -2 -9 wells and facility, at the end of the Shirleyville Airstrip (a.k.a., Nicolai Creek Airstrip), The location is in Sec. 30, T1ON, R12W, and the GL is about 20'. 2. Build a 160' X 255' gravel pad on the site and drive 13 -3/8" 68# K -55 BFW conductor to +/- 80' below GL, not necessarily in that order. Build sufficient emergency cuttings containment for planned drilling program on the 1 -2 -9 pad, and build containment for diverter line using silt fence. 3. Install cellar & mousehole. Cut off conductor as needed to accommodate diverter system. Drilling Procedure 1. File & insure all necessary permits and applications are in place. 2. MIRU AWS #1 in drilling configuration. Install 13 -5/8" VG LOK head. 3. Rig up diverter & mud loggers. Test & calibrate all PVT / gas sensor equipment. Provide 24 -hr notice to BLM & AOGCC inspectors for chance to witness diverter test. 4. Notify BLM & AOGCC when ready to start drilling operations. 5. Prepare spud mud system / weight up to 10.0 ppg. Load, strap & drift 650'+ of 9 -5/8" 53.5# L -80 BTC surface casing (may have some 40# K or N in string also). Note that float shoe and float collar have been "bucked on" short joints in Kenai — locate and bring to location. 6. PU 12 -1/4" mill tooth bit & drill to -650', using 8" & 6 -1/2" stabilized BHA w/ float sub and drilling jars. Watch for gas in shallow coals and sands. Attempt to TD in siltstone or claystone, avoid setting surface shoe in a coal bed or sand. If possible, adjust TD to put cement head at floor. (Short joints are available to facilitate this). 7. Make wiper trip to conductor to condition hole for running 9 -5/8" surface casing, POOH, LD 12 -1/4" BHA. 8. Run & cement new 9 -5/8" 53.5# L -80 BTC casing @ +1 -650', installing 1 centralizer / joint centered on the 1 4 joints above shoe, & 1 centralizer every 2nd joint across the collars there after. Shoe joint connection at float shoe and float collar must be Baker - Locked. Cementing will be single stage using 13.0 ppg accelerated Type I cement at Prepared by Ed Jones Page 1 of 11 Rev. 1.0 Aurora Gas, LLC • Iicolai Creek #11 Drilling Plan 100% excess volume. Overdisplace by 1 bbl if plug doesn't bump. Be prepared to treat cement returns with retarder. Leave 6" to 18" of cement in cellar to seal bottom. 9. RD cementers, nipple down diverter, cut casing and install 11" 3M wellhead, 10. RU and test 11" 3M BOP stack and 5M choke manifold. Test stack and surface l equipment to 3,000 psi. Pressure test 9 -5/8" casing to 1,500 psi for 15 minutes or as required on approved Permit to Drill. Mud weight to drill out should be at least 10 ppg at this point. 11. PU 7 -7/8" Mill Tooth Bit & 6 -1/2" & 4-%" stabilized BHA w/ float sub and drilling jars. RIH. Drill out shoetrack. Condition / treat mud as needed for cement contamination, dril 20' new formation. Pull back into shoe & perform FIT / LOT up to 16.0 ppg EMW 12. RIH and drill 7 -7/8" hole to 3400' MD /TVD TD or other depth as directed by Aurora Gas geologist (may slightly deeper, depending upon top of Carya 2 -5). Monitor well and volumes carefully. Be prepared to shut well in and weight up immediately if flow or excessive gas build up in mud is noticed. Monitor hole cleaning and drilling trends, make wiper trips every 500' or so, as needed (back into shoe first time, then just above last wiper trip point thereafter, or as needed). Anticipated mud weights required are 10 ppg – 13.0 ppg. Do not exceed fracture gradient determined in step 11. If possible, adjust TD to put cement head on floor. While drilling, load, tally & drift 5 -%2" casing on racks. 13. Condition hole, short trip and prepare for running wireline logs. 14. POOH, rack back drillstring. RU wireline BOP's and lubricator and logging tools. Log 9 -5/8" cased hole section w /gamma ray sensor. Log OH section with logging suite including resistivity and porosity logs as directed by Aurora Gas. RD wireline. 15. RIH w/ 7 -7/8" drilling assembly to TD & condition hole for running 5 -'/2" casing. Ensure cementing head has proper connections (8 Rd LTC) or proper crossover and is available for quick rig up. 16. POOH while laying down drillpipe & BHA, RU to run casing. Verify cementer's equipment is ready. 17. Install 5 -' /2" pipe rams. / 18. Run 3400' of 5 -'/2" 17# N -80 LTC casing, installing 1 centralizer per joint centered on 1St 4 joints above shoe, 1 centralizer every 2nd joint in open hole & every 3 joint inside surface casing (use Turbolator centralizers below /thru each pay sand). Shoe joint connection at float shoe, float collar must be Baker - Locked (80' shoetrack). While running casing, fill every 3 joint. Be prepared to wash to bottom. 19. RU cementers, cement per attached cementing program from TD to surface. A sufficient amount of accelerated 12.0 ppg light weight Type 1 w/ 20% Poz Powder lead cement will be pumped to cover from 1200''up thru the annulus of 9 -5/8" to surface: This will be followed by sufficient amount of 14.8 ppg Type I tail blend cement to cover from TD back to 1200'. Excess will be calculated using caliper log data —top of tail slurry will be determined following evaluation of the logs. Plug will be bumped with clean brine. If possible reciprocate pipe while displacing cement. Land casing & WOC. 20. RD cementers, nipple down stack, land casing in slips & cut casing. Prepared by Ed Jones Page 2 of 11 Rev. 1.0 • Aurora Gas, LLC icolai Creek #11 Drilling Plan 21. Install 11" X 7- 1/16" tubing spool, 7- 1/16" X 11" DSA, mud cross and reinstall BOP stack. Pressure test BOP and surface equipment to 3,000 psi. Pressure test casing to 2,000 psi for 15 minutes and record results. 22. Install 2 -7/8" pipe rams. 23. RIH w/ bit & casing scraper on 2 -7/8" tubing to float collar. Displace well w/ filtered KCUNaC1 brine (wt. to be determined from XPT data). Continue to clean brine for perforating by running through centrifuge & filtering. POOH. Strap tubing on TOH to validate tally. A MORE DETAILED PROCEDURE WILL BE PROVIDED AT THIS POINT INCLUDING PERFS 24. PU wireline BOP's & lubricator, pressure test all against casing to 1500 psi (or higher if XPT indicated higher gradients), PU GR/CBL /CCL & log 5 -1/2" casing to surface. LD logging tools & PU perforating guns, RIH to depth as determined from OH logs and perforate zones of interest. Watch for pressures in casing after shooting. POOH, LD perf gun, RD wireline, 25. RIH w/ bit & casing scraper on 2 -7/8" tubing to float collar. Circulate perforating debris from hole. Continue centrifuging & filtering brine until cleaned up. POOH. LD bit & scraper. RU Aurora well test unit, including flare stack. 26. Pick up & assemble completion assembly which will consist of mechanical set packer w/ on -off tool for sump packer to be set above deepest perforated zone, then 2 (or 3) hydraulic packers w/ sliding sleeves between packers —all sliding sleeves are to be closed and a pump -out ball -seat below deepest packer. RIH with completion on new 2 -7/8" 6.5# J -55 8 rd tubing & set completion at appropriate depth, filling tubing as running. Space out, hang off in tubing head & lock down. Drop ball and pressure tubing to 3000 psi (or as required) to test and to set packers. Increase pressure and shear out ball. Install BPV. ND BOP. NU and test tree. Pull BPV. 27. RU & swab in deepest zone. After well cleans up, perform flow test —get stabilized rate (1 hour minimum). Shut in well & record pressure buildup until stabilized with no change in one hour. DO NOT KILL, but run blanking plug and set in X nipple below deepest packer. 28. Add needed KCl water cushion to tubing (1000' above sliding sleeve). Open deepest sliding sleeve. Test well as per Step 29. DO NOT KILL, but close sliding sleeve. 29. Repeat Step 30 for remaining shallower intervals (1 or 2). 30. Open zones for initial production (depending upon pressures and test results -- likely the 2 -4.2 and deeper) —flow to clean up. Shut in. Set BPV in tree. Release rig, RD, and move rig. 31. Pull BPV. Run 4 -point test of initial production zone as per Procedure provided at that time. RD test unit. 32. Clear & clean location. Hand well over to production. 33. File completion reports with proper agencies. Prepared by Ed Jones Page 3 of 11 Rev. 1.0 Aurora Gas, LLC icolai Creek #11 Drilling Plan Site Access Nicolai Creek #11 will be accessible via existing gravel roads from NCU 1 -2 -9 pad, which will be improved (gravel added). Rig Aurora Well Service, Rig No. 1 (AWS 1) will be used to drill the NC #11 well. The Alaska Oil & Gas Conservation Commission has information on this rig and equipment as it has been in use for the last (6) years on other Aurora Gas operations. The pits, BOP system & mud equipment configuration will be the same as that used for previous work. Survey Program The 12-1/4" surface hole and the 7 -7/8" production hole will be drilled vertically, and the survey program will consist of single -shot surveys as required to be obtained at 500' intervals in accordance with rules laid out in 20 AAC 25.050 (a) (1) & (2). ✓ Logging Program Mud loggers will be on site for the duration of drilling activities. Schlumberger will provide wireline logging services as proposed below: Kaloa #3 Proposed Logging Program Well Section Depths (ft) OH CH Log Type 12 -1/4" Surface 0' — 650' Al N /A: No open -hole logs planned for surface at this time. GR only in cased hole. 7 -7/8" Production 650' —3400' A/ Platform Express: Array Induction, Compensated Neutron, Hole Litho - Density, SP, GR, and possibly DSI and/or FMI/DM.. Also XPT and, possibly, Sidewall cores. 5 -1/2" Int. Csg 650' —3400' I GR/CBL /CCL Surface — TD 94' — 3400' Ai Mud Logging Services ✓ BOP Equipment Aurora Gas, LLC will use the same BOP system they have been using for the last 6 years (except that 12" diverter line was added in 2008), which will consist of the following: Prepared by Ed Jones Page 4 of 11 Rev. 1.0 Aurora Gas, LLC • •volai Creek #11 Drilling Plan 12 -1/4" Surface Hole While, drilling the 12 -1/4" surface hole, a 13 -5/8" 5M annular w/ 13 -5/8" diverter spool & 12" diverter line will be used: an exception to 20 AAC 25.035 (c)(1)(A), requiring that the diverter line outlet size be at least 16" diameter or (B) at least as large as the hole size being drilled, will be requested. 7 -7/8" Production Hole An 11" 3000 PSI WP Schafco (Shaffer Equivalent) BOP system will be used which is configured with an 11" 3000 PSI WP annular preventer, (1) 3000 PSI WP double gate with a set of pipe rams installed sized to fit the pipe being run and a set of b • rams and (1) 11" 3000 PSI WP rated drill' spool. BOP tests will be performed to The annular preventer will be tested t 500 si. Again, this is the same equipm urora has been using all along and informs ' on the system is on file at the AOGCC. Drilling Fluids The drilling fluids will be furnished by Baroid, who has extensive experience with drilling activities in this area. An experienced mud engineer will be on site at all times while drilling to monitor properties and make recommendations. Drilling Fluid Properties While Drilling 12 -1/4" interval to 650' Beluga Formation Base Fluid Fresh or produced water Density 10 -11 ppg PV 10 -30 YP 30 -40 API Filtrate not controlled Total Solids 15 — 25 % Bentonite Gel (Aquagel) mud system Drilling Fluid Properties While Drilling 7 -7/8" interval to 3400' Beluga and Tyonek Formations Base Fluid 3% Kr Density 9.6 -1,5.Q''ppg PV 6 -15Y YP 13 -20 API Filtrate < 5 Total Solids 10 —15 % Low Solids Non - Dispersed (LSND) System Prepared by Ed Jones Page 5 of 11 Rev. 1.0 Aurora Gas, LLC • lticolai Creek #11 Drilling Plan Drilling Fluid Handling System Shale Shaker, Mud Cleaner, Centrifuge, PVT monitors Drilling Waste Disposal The cuttings will be mixed with Portland cement, put into Super Sacks and transported to the Kenai Borough landfill on the Kenai Peninsula. Drilling mud will be held in tanks for reuse or injection at the Aspen Disposal Well. Brine will be placed in tanks for use in future wells. Casing / Cementing Program All casing is new. Analysis (attached) indicates casing program as designed provides adequate safety factors for this well. All casing strings with the exception of the 13 -3/8" conductor will be cemented in place using industry standard casing cementing techniques utilizing a casing shoe, float equipment, top and bottom wiper plugs and centralizers installed as needed. 13 -3/8" 68# K -55 Conductor Analysis and Cementing Program The conductor for Kaloa #3 has been installed by drilling/driving the 13 -3/8" pipe to 80'GL/95' RKB. Joints are welded together and a drilling shoe was welded to the bottom joint. No cementing is required. 9 -5/8" 36# K -55 LTC Surface Casing Analysis and Cementing Program The 9 -5/8" surface casing will be cemented from the proposed setting depth of 650' to surface with an accelerated 13.0 ppg accelerated Type 1 cement system. Capacities: 9 -5/8" Csg. Capacity = .0773 bbl /ft 9 -5/8" Csg X 13 -3/8" Conductor Capacity = 0.0597 bbl /ft 9 -5/8" Csg. x 12 -1/4" 011 Capacity= .0558 bbl /ft System Volume: 9 -5/8" X 13 -3/8" Annulus: 80 X 0.0597= 4.8 bbl 12 -1/4" OH x 9 -5/8" Csg: (650' -80) x .0558 bbl/ft x 2 ,1 /o excess) = 63.6 bbls Shoe Jt: 43' x .0773 bbl/ft = 3.3 bbls Total Surface Cement Volume =71.7 bbl Actual volumes to be re- calculated at time of running casing due to potential variation in actual depth from planned. Cement System Weight (ppg) bbl cf sx Accelerated Class G 13.0 71.7 402 220 Yield/1.83 cf/sx Pleasb see attached 9 -5/8" surface casing analysis and specifications. Prepared by Ed Jones Page 6 of 11 Rev. 1.0 Aurora Gas, LLC colai Creek #11 Drilling Plan 5 -1/2" 17# N-80 LTC Production Casing Cementing Program The 5 -1/2" production casing will be cemented in fully from the proposed set depth of 3400' to surface. A 12.0 ppg accelerated lead light- weight "G" cement followed with a 14.8 ppg Type I tail cement system will be used. (The top of the tail may be adjusted upward following the logging program, dependent upon the location of upper most potential pay). This program is designed to insure the intended perforating / production intervals are isolated with tail blend. Capacities: 5 -1/2" 17# csg capacity = .0232 bbl /ft 5 -1/2" 17# csg X 7 -7/8" OH capacity = .0309 bbl/ft 5 -'/2" 17# csg X 9 -5/8" 36# annular capacity = .0479 bbl /ft Lead System: 9 -5/8" x 5 -1/2"Csg: 650' + (2600 -650') 7 -7/8" open hole 650' x .0479 bbls /ft x 1 (0% excess) = 31.1 bbls Lead Cement Volume = 31.1 bbl +550' X .0309 X 1.25 (25% excess) =53 bbl Tail System: 7 -7/8" OH x 5 -1/2' Csg: 3400' -1200' = 2200' 2,200' x .0309 bbl/ft x 1.25(25% excess) =85.0 bbls Shoe Joint: 85' x .0232 bbl /ft = 2.0 bbls Total Tail Cement Volume = 87.0 bbls Actual volumes will be calculated at time of running casing due to potential variation in depth from planned. Cement stem Type Cement Weight (ppg) bbl cf sx Lead C! 2.86 f /sx Type I 12.0 53 ' 297 104 Tail ') 1 3 cf /sx Type I 14.8 87.0 488 362 .- Please see attached 5 1/2" production casing analysis and specifications. Pressure Calculations Maximum Anticipated Surface Pressure From offset wells in the immediate area and actual pressure data from the nearby offset well NC #11, maximum anticipated bottom -hole pressures should not exceed 1650 psi at 3,400 ft. Pressures measured at the Nicolai Creek #1B well indicated a gradient of —.485 psi /ft with a bottom -hole pressure of 1730 psi recorded at 3560'. However, the gradients in the NCU #9 were higher, up to 0.548 psi /ft at 820', but were decreasing with depth to 0.463 psi/ft at 1832'. Maximum anticipated surface pressures "MASP" be calculated by subtracting the gas gradient of .1 psi/ft from pore pressure gradient o .55 psi / ft and multiplying by the total TVD v depth. Maximum Anticipated Surface Pressure = (.55 .1f) * 3400' = 1530 psi / Prepared by Ed Jones Page 7 of 11 Rev. 1.0 Ili Aurora Gas, LLCcolai Creek #11 Drilling Plan A formation integrity test to 16.0 ppg EMW @ 660' will be conducted while drilling NC #11, as this has become Aurora's standard test in this area. Assuming casing shoe strength of 16.0 ppg EMW (or 0.83 psi/ft) our estimated Maximum Allowable Surface Pressure during the 7 -7/8" interval is expected to be Maximum Allowable Surface Pressure = (.83 -.1) *660' 482 i si Drilling Hazards �� Shallow gas Shallow gas is a known hazard which exists throughout the area. The northwest side of Cook Inlet is noteworthy for its shallow gas hazard. All responsible personnel will be made aware and a notice of such hazards will be posted in the rig doghouse. There is no record of H2S in the region, however; a gas detection system capable of detecting H2S as well as methane will be ✓ installed on the rig with detectors at the floor level, the shale shaker and in the cellar. Coal Seams The Cook Inlet region is rich in coal seams, inter- bedded between the sands, gravels and shales that make up the Beluga and Tyonek formations. Drilling into a coal seam will appear to be a drilling break when drilled with a tri -cone bit. The major hazard of drilling into a coal seam without observing the proper response is the risk of stuck pipe. The proper course of action for preventing stuck pipe is two -fold. First, prior to drilling, insure the drilling fluid system is up to par, per recommendations from the on -site mud engineer. The second step to successfully - drilling through coals in the Cook Inlet area is to not get greedy when coals are encountered. When a coal has been encountered, pull back above coal after drilling into it, and circulate, allowing the coal to stabilize. Re- enter, drill some more, and pull back out again. Continue in this fashion until successfully through the coal bed. The key word in successfully drilling the coal beds is pritien . It should be remembered that coals behave plastically, and will flow under . the weight o overburden. The deeper the coal, the more pronounced this tendency becomes. For this reason it is critical to maintain the proper weight and viscosity of the drilling fluid to properly remove the coal cuttings, and to hold flowing coals in place. Again, heed the recommended drilling fluid program and advice offered by the on -site Mud Engineer. Well Proximity Risk There are 7 existing wellbores in this field, the Nicolai Creek Unit No.'s 1, 1A, 1B, 2, 4, 6, and 9, all with surface locations about 1700' or more to the east of the projected #11 BHL. All but #9 were directionally drilled, but the #1, #1A and #1B are the closest, going to the southwest of their surface locations. Thus, the closest well bore is the #1/#1A wellbore, which will be about 1525' om the BHL of the #11. Thus, there is no well proximity risk. Other Risks Sticky bentonitic clays, boulders, lost returns & differential sticking with overbalanced muds and gas influx while cementing or swabbing while tripping pipe. Prepared by Ed Jones Page 8 of 11 Rev. 1.0 Aurora Gas, LLC icolai Creek #11 Drilling Plan 2 7/8 6.5# 8rd EUE J -55 Tubing =Aurora Gas, LLC 4 Nicolai Creek #11 ,e � �� �� � ' " „ V e k V * . 13 -3/8 68# Structural Proposed Configuration V ; V 4, ' !Z LflS ! h ` Conductor driven to 8 GL Drill 12 -1/4" Hole to 650' 9 -5/8" 40# K -kk and, 53.5# L-80 r G � i � " Surface Casing set at 650' g . 91 1 117 2 -7/8" x 5 -', " annulus to be ,� F. g n ` 4i Cement w /13.0 ppg Type I displaced over to inhibited packer r 1 Prospective Beluga Pays Tsuga 2-6 1250' " Tsuga 2 -7- 1320' "0 Tsuga 2 -8- 1820' M „ ProspectiveTyonek Pay Tops E o r { a t ' C wx / 200 Carya 2 -1.1- 2030' , __.__.._ TO Carya 2 -1.2 - 2300' Hydraulic Set Packer @ 1250' Carya 2 -2.1 2480' F Carya 2 -2.2 -- 2600' ii,V 4164 Carya 2 -3 - 2830' j Carya 2-4.2- 3190' �_ Sliding Sleeve @ -1350' Tsuga 2-7 C:;:::: O 4 , e ' :" b y e Perforation Intervals to be rHydraulic Set Packer @2000' determined by open -hole logging. ', KV ,- -cam Carya 2 -1 4 . ., . fi t 0 . ' Sliding Sleeve @ -2600' MD Carya 2 -2 4 .. , yi _ -- ' : , 2 7/8" 6.5# EUE 8rd Tubing w/ On- — 0 Off Tool on Mechanical Packer @ i 2800'MD w/ 231 profile X nipple Carya 2 -3 �Sr " 1 1 Carya 2-4 31:11," 11-ptir 14, rY Drill 7 -7/8" Hole to 3400' , MD/TVD r g� "r 5'A 15.5# K -55 & 17# N-80 Casing to 3400' q, i 1 G rtikiN ` J' h j•1 � 1 ~ L) Estimated PBTD @ 3315' Prepared by Ed Jones Page 9 of 11 Rev. 1.0 Aurora Gas, LLC i Cree #11 Drilling Plan ' r,, CREEK 11 DRI LLING TIME 0 'M as s- �' *�fi y ., a a ",� x f 1 * { tt �� m^a '' / k d�.' "* m 3 �.t�` 's } "4'43,, ° �� 1 ;4'0.4 4:'# 1 „ n^r k (k i ° ( u e p i ` - 5 , 1., a :m '�'a'�rfl4` as i $ a! k j y , � < ° 4 ,spa yr „„,,A44,-44444 a � � �, � ' 'a al ' i .." t ;14.1V1 4 uti �� it 500 � s w 3 7 # f r Cok m e i i 4 741/2 t +.�u� y, 7,414- { ' ''""1 �” k m g S h , Y v a ‘L 9 k } '? �y. t�. a 'F �"3x" a �h ''' 1000 ' 0 14 , t ✓ a° V ' ; r t !! ' 4 h §. —1500 � � s "�` �- ama . r � � r � — � : � ' . < " a +, x k.7 -�r 4 .+- 4 r 4 ''&;,;:4'-442-411141, . 1 4 1 + 3 ' 1' , a " ' ` � sr.;.r ti 1... ' a � @ w�? � - tSer 0 -2000 E. -" ' 4,' z fir' ; 6 `� ,, - s > � », ''r4 '7' �' . `a, ,s - - s IA 151- 11441,* . t % '` " 1 i ii 1 ��h 8 4 , ° -24 14 � �r �* r 4 � � � . � � ' ' a 1 a 4; � -'a ,� � � . � ' � , � iyr C� �k� M �' " .a 0 i r + I ° x � ' r l 1 4 r3 0441,1 1" 2500 7 ' 4 , r r t s b k $ " { r � i n :4< � �h G rp • � "�' t � � t A �,�� r � � �n rx 4 X i ce m l'ah ,s ' r + s k � � y a p � � ,,yy� � � E ^�`�„'b �� w � �� + ^•!! 4 i x � .fix ,�� 3 n � S_ r � d �.� S3 � 4 � eir - 25 00 ', 4 . ,. 1 5T* r r m r i P " r a uy s r F t m`� a f s"d" € . 'e rd , � f� P`u .a a a Sk l': � ' S �.1£ 95 r ' � r�u li O ra p� t �� ��� 3 � � d i � �� �� 3 C s in k ... ^�,' - F �`x a, F : } �,xp a " d s w' t —3500 1 a ;t -,+-- ,�,,,,,, 3 " �2 .4. 04 -, �.., .r„ - e '.-.. r DAY Days 1 -3: Drill 12 -114" Hole Days 3 -6: Run and cement 9 -5/8" casing Day 6: Test cas d out w/ 7-7(1/8:1\4' bit and run FIT, drill 7 -7/8" hole. Day 6 -1 4: drill 7 -7/8" hole to 3 D / TVD Days 15 -16: Days 17: Run 5 -1/2" casing and Log cem ent. Days: 1 - - -: Complete and test well. Prepared b Ed Jones Page 10 of 11 1.0 Rev. Aurora Gas, LLC •colai Creek 411 Drilling Plan NICOLAI CREEK #11 Summary of Drilling Hazards POST THIS NOTICE IN DOGHOUSE Ai There is potential for abnormal pressured shallow gas. Ai There is potential for stuck pipe in coals encountered while drilling from surface to TD. Short trips as dictated by drilling trends. Ai There is no H2S risk anticipated for this well. - Ai Due to potential for shallow gas kick, very little response time will / be afforded to respond. PVT and gas detection systems must be fully operational and functioning at all times, visual flow checks and pit level monitoring are critical. CONSULT THE NICOLAI CREEK #11 WELL PLAN FOR ADDITIONAL INFORMATION Prepared by Ed Jones Page 11 of 11 Rev. 1.0 NICOLAI CREEK #11 Casing Properties and Design Verification Casing Performance Properties: Aurora Gas Nicolai Creek #11 Tensile Strength Section Internal Collapse Size Weight Yield Resistance TVD MD MW MASP (Inches) lb /ft Grade Cnxn (psi) (psi) Joint Body Length (ft RKB) (ft RKB) (prig) BF (psi) 9 -5/8" 53.5 L -80 BTC 7930 6620 1329000 1244000 650 650 650 10.5 0.84 482 9 -5/8" 40 K -55 BTC 3950 2570 843000 630000 650 650 650 10.5 0.84 482 • 5 -1/2" 15.5 K -55 BTC 4810 4040 300000 248000 3400 3400 3400 11 0.83 1530 5 -1/2" 17 N -80 LTC 7740 6280 348000 397000 3400 3400 3400 11 0.83 1530 Design Safety Factor* Size Tensile Burst Collapse 9 -5/8" 45.5 16.5 22.8 9 -5/8" 38.6 8.2 8.9 r 5.5, 15.5 6.8 3.1 2.5 „ 5.5 17 N 7.2 5.1 3.9 -° * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factors are calculated at the surface using zero backup on the outside and MASP on the inside. Collapse design safety factors are calculated at the casing shoe using the maximum expected mud weight to be used at the 0 shoe depth on the outside and the entire cased hole evacuated except for a gas gradient on the inside. Casing Setting Depth Rationale 9 -5/8" 650' MD / 650' TVD Surface casing to stabilize shallow formations provide an anchor for the BOP stack and provide shoe strength in the event of a kick. 5 -1/2" 3400' MD / TVD Production casing to stabilize and isolate producing interval for production operations. Ed Jones 6/4/2009 • Aurora Well Service Rig No. 1: Proposed Surface Diverter System • Bell Nipple Flow Line to Pits Fill Line f � 1 r 13 -5/8 ", 5000 psi WP Annular Preventer Hydraulically Operated 12" Valve � I j It �� 13 -5/8 ", 5M ! = 11 ... Drilling Spool / Mud Cross " Diverter Vent Line 4,1611/4 13-3/8" 13 318" Conductor Pipe with 13 -5/8 ", 5000 psi WP Flange welded on top i • Aurora Well Service Rh No. 1: Proposed 3M BOP Con guration Bell Nipple with flow line to pits Fill Up Line '3M Schaffer Annular Preventeri Pipe Rams sized to work string. l 11" 3M Double Gate w/ 3/12" pipe rams installed. 11" 3M Mud Cross Blind Rams 3" 5M Manual Valve (Kill Line) 3" 5M Manual Valve (Choke Line) 3" 5M Hydraulic Valve � (Kill Line) - �► ■• 3" 5M Hydraulic Valve `` Iii T ill •1 1 >= �!� (Choke Line) Fluid flow direction while reverse circulating 11 ° "x 3M .1114 11 Simy +l 0 2" 3M Manual Valves On Wellhead Braden Head Nrir 9 5/8" Casing 13 3/8" Conductor Aurora Well Service Rig No. ) 1 Proposed Choke / Kill Manifotu' All valves are 3" rated at 5000 psi. Inlet from Output to Pits Power Swivel (Reverse Circulation Mode) 1 (2" 5M Rated Valves r . Hydraulic Remote Activated choke — Inlet from BOP Choke Line !� 3" 5M Rated Valves ** Ado Bleed Flare Line to 3" 5M Rated Open Flare Pit 3" 5M Rated ,� Valves Valves ■ow ;.1111 �/o1111 Manual Choke 2" 5M Rated al - REP Ives To Gas Buster "Atmospheric Degasser" • 1 . WAurora Gas, LLC www.aurorapower.com June 10, 2009 RECEIVED Mr. Dan Seamount, Chair J 2009 Alaska Oil and Gas Conservation Commission ,Alaska Oil & Gas Cons. Commission 333 West 7 Ave., Suite 100 Anchorage Anchorage, Alaska 99501 RE: Application for Permit to Drill: Nicolai Creek No. 11 Dear Mr. Seamount: Aurora Gas, LLC hereby applies for a Permit to Drill an onshore gas exploration' well in the Nicolai Creek Field south of the village of Tyonek. The well is planned as a vertical well targeting the Upper Tyonek Formation to test for gas. Please refer to the attached Drilling Plan. The rig to be used is the AWS #1. The rig's well control systems are on file with the Commission. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill. 2) A plat showing the surface location of the well. 3) A Time versus Depth plot. 4) Proposed casing program. 5) Proposed cementing program. 6) Proposed drilling fluid program. 7) Proposed summary drilling program. 8) Summary of Drilling Hazards. 9) Schematic of the proposed welibore and completion. 10) Aurora Gas does not anticipate the presence of 1-12S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. 11) The following are Aurora Gas' designated contacts for reporting responsibilities to the Commission: 1400 West Benson Blvd., Suite 410 • Anchorage, AK 99503 • (907) 277 -1003 • Fax: (907) 277 -1006 6051 North Course Drive, Suite 200 • Houston, TX 77072 • (713) 977 -5799 • Fax: (713) 977 -1347 • • Mr. Dan Seamount June 10, 2009 Page 2 1) Completion Report Ed Jones, Executive Vice President (20 AAC 25.070) (713) 977 -5799 2) Geologic Data and Logs Andy Clifford, VP - Exploration (20 AAC 25.071) (713) 977 -5799 Aurora submitted a Spacing Exception application on September 17, 2007. If you have any questions or require additional information, please contact me or Mr. Ed Jones at (907) 277 -1003. Sincerely, AURORA GAS, LLC A� fi Bruce D. Webb Manager, Land and Regulatory Affairs enclosures TRANSMITTAL LETTER CHECKLIST r WELL NAME / �l . `�- 9� ,474' /I PTD# 6 -7 Development Service Explo ato y Stratigraphic Test Non -C nventional Well ( Leh h ea 7 a , • FIELD: - � t— l_.Yz�- POOL: ( � �� f s � . 1 i c' , �C / ; ;. t' � : Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to f�pliance with 20 AAC EXCEPTION " 25.055. Approval to perforate an(produc / inject is contingent upon issuance of a conse ation ZSrd r approving a spacing exception. r a , ,fi (.a Y L c . assumes the liability of any protest to pacin exqep ion that may occur /(_ the s ts�cced /(1 ' ' C'e- /Vi4t.ei( is LXJ ( lF `, eiiciS 8 //6 DRY DITCH All dry ditch sample sets submitted to t e Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or ` 73/67 from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST' Field & Pool NICOLAI CREEK, SOUTH UND GAS - 560520 NICOLAI CREEK, BELUGA UND GAS - Well Name: NICOLAI CREEK 11 Program EXP Well bore seg El PTD #: 2090670 Company AURORA GAS LLC Initial Class/Type EXP / PEND GeoArea 820 _ Unit On /Off Shore On _ Annular Disposal ❑ Administration 11 Permit fee attached NA '2 Lease number appropriate Yes Need land /lease plat: requested from operator 7/1 and again 7/8. Received 7/10. Well is located 3 Unique well name and number Yes on former federal lease AA -8426, which was conveyed to the state on June 10, 2009. 4 Well located in a definedpool No Exploratory (delineation) well 5 Well located proper distance from drilling unit boundary No —200' from boundary between Fed lease AA -8426 and State ADL 17595. However, Federal 6 Well located proper distance from other wells No lease AA -8426 was conveyed to the state on June 10, 2009. Nicolai Creek Unit 1B lies 1 7 Sufficient acreage available in drilling unit Yes about 1700' away. Only open wellbore in Section 30. 8 If deviated, is wellbore plat included NA Vertical well 9 Operator only affected party Yes ,10 Operator has appropriate bond in force Yes 1 11 Permit can be issued without conservation order No Appr Date 12 Permit can be issued without administrative approval Yes D 7/30/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 115 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 1 17 Nonconven. gas conforms to AS31.05.030O1.A),0.2.A -D) NA j18 Conductor string provided Yes 13 -3/8" @ 95'. Engineering X19 Surface casing protects all known U$DWs Yes Set @ 650'. 20 CMT vol adequate to circulate on conductor & surf csg Yes Adequate excess cement. 21 CMT vol adequate to tie -in long string to surf csg Yes 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes Adequate safety factors. 24 Adequate tankage or reserve pit Yes AWS Rig 1. 25 If a re- drill, has a 10 -403 for abandonment been approved NA New well. 26 Adequate wellbore separation proposed No Spacing exception required. 1 27 Ifdiverter required, does it meet regulations No Vent line variance required. Appr Date 128 Drilling fluid program schematic & equip list adequate Yes Max MW 13.0_ppg. WGA 6/30/2009 29 BOPEs, do they meet regulation Yes 3M BOPE. 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP 1525psi; test ram BOPE to 3000 psi, test annular BOPE to 1500 psi. • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated based on nearby wells that have penetrated the same section. Geology 36 Data presented on potential overpressure zones Yes Expected max. reservoir pressure is10.6ppg EMW; will be drilled with 9.6 to 13.0 ppg mud. Appr Date 37 Seismic analy of shallow gas zones No - Three wells have penetrated the same geologic section within about 1/2 mile SFD 6/29/2009 38 Seabed condition survey (if off- shore) NA of the proposed location. Mud loggi unit and crew will be used during drilling. Shallow gas hazards 39 Contact name /phone for weekly progress reports [exploratory only] Yes discussed in Drilling Hazards Summary. Bruce Webb 907 - 277 -1003 Geologic Engineering Public SPACING EXCEPTION NEEDED: Well lies within 3000' of NCU 1B and NCU 9. Hearing scheduled for August 11, 2009. Commissioner: Date: Commission r: Date Commissioner Date Hearing vacated July 29, 2009. Spacing exception decision will be published following the 30 -day public comment period, which 8 -3 -0 ends at 4:30 PM on August 10, 2009. SFD • . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1 Company AURORA GAS, LLC 1 Scblumberger Well Name NICOLAI CREEK NO. 11 1 1 Field Name NICOLAI CREEK UNDEF GAS /BELUGA UNDEF GAS 1 Field Location 3 365' FNL & 1 434' FEL 1 APIN 50- 283 - 20135 -00 1 Engineer's Name K. MACPHAIL O () 1 Date 13 -SEP -2009 Report Date 18- Sep -2009 Log Analyst R.Heath PressureXpress Data Evaluation Report Innovations in Formation Testing PD Plot 7 Ver 7.1.56 Page Report Cover Written Comments 3 Test Point Summary Table 4 Header 5 Pressure Gradients 6 pres_vs v2 7 XY MUD Before vs MUD After 8 Gauge Comparison Table 9 Test Point Table 10 Polaris Interpretation 16 Written Comments Schlumberger Objective: 1 Compile an Express Pressure Tool (XPT) evaluation report that includes plots of formation pressures versus depth, fluid gradients, a table of test point data, and individual plots of each test draw-down/build- up sequence. Comments: Run ES -TWO was conducted with the XPT -GR tool on 13- Sep -2009 in the 7.875" hole, from approximately 923 ft to 3391 ft (Measured Depth). Note: Because this well is considered to be a vertical well, no survey data was loaded and all plots showing "TVD" depth have the same reference as "MD" ' (measured depth). A total of 28 tests were evaluated from data supplied by the field engineer. Of those 28 tests, 20 were ' completed with normal results, 6 were 'Dry Test', and 2 were 'Unrecognizable'. Overall, the quality of the tests was good - see the comments on specific tests in the Test Point Table. The test quality is graded by color, with Green being the highest (see the table below for grading explanation). 1 Formation Pressure Quality Grading Description Color Quality# Description Examples Red 0 through 3 No or Unreliable Formation Pressure Tight, Building, etc -- N of Close To Being Stabilized Yellow 3 through 7 Fair Formation Pressure ' - Green 8 through 10 Good Formation Pressure Close To Being Stabilized Build Up Stabilized 1 1 1 1 1 1 1 1 NICOLAI CREEK NO. 11 3 Schlumberger • Test Point Summary Table 1 Test Types Quantity Volumetric Limited draw -down 19 Dry Test 6 Unrecognizable 2 Volumetric Pretest 1 TOTAL 28 Gauges CP_SAP 28 Runs [Color ES -TWO 2 ES -ONE 26 Formation Pressure Quality: Color 0 (no pressure) - 10 (best) 10 15 7 4 4 1 0 8 Drawdown Mobility Quality: Color 0 (no pressure) - 10 (best) 10 19 7 1 0 8 1 I 1 I I NICOLAI CREEK NO. 11 4 t 1 Schlumberger Header 1 1 COMPANY: AURORA GAS, LLC 1 WELL: NICOLAI CREEK NO. 11 I FIELD: NICOLAI CREEK UNDEF GAS /BELUGA UNDEF GAS Borough: KENAI : ALASKA I Z U J I CO C 0 Schlumberger LL W J W Y T z J 3 365' FNL & 1 434' FEL Elev: K.B. 20 ft 0 Z Q LAT. 61.0125 DEG N G.L. O ft Z o o rtt o o LO 151.9680 DEG W D.F. 20 ft Y 0 s-, z a .0 Permanent Datum: GROUND LEVEL Elev: 4 ft I J Log Measured From: KELLY BUSHING 16ft above Perm. Datum Drilling Measured From: KELLY BUSHING T E. a Max Deviation Latitude Longitude 1 0 � t _ E OS ii 3 '' V 0 0 Logging Date 9/13/2009 Run Number ES -TWO I Depth Driller 3600 ft Schlumberger Depth 3546 ft Bottom Lo. Interval 3391 ft I Top Lo. Interval 923 ft Casing Drilling Size @ Depth 9.625 in 631 ft Casing Schlumberger 0 ft Bit Size 7.875 in I Type Fluid in Hole Densit Viscosity 6% KCL / EZ MUD DP 13.1 lb/sal 64 cp Mud Fluid Loss PH 3.6 ml 9 Source of Sample I RM @ Measured Temperature 0.19 @ 76.3 DEGF @ RMF @ Measured Temperature 0.14 @ 76.3 DEGF @ RMC @ Measured Temperature 0 @ 0 DEGF @ I Source RMF Source RMC RM @ MR RMF (:r 0.15 97 DEG' 0.11 97 DEG -_ -- Maximum Recorded Temperatures 0 DEGF 0 DEGF 0 DEGF Circulation Stopped Time I Logger On Bottom Time 21 45 Unit Number Location KENAI Recorded By K. MACPHAIL Witnessed By C. HELGESON 1 1 1 NICOLAI CREEK NO. 11 5 Schlumberger I Pressure Gradients Mud Column Gradients , Formation Gradient Gauges Gradient l Density j Gradient Top ft Base or RI Error % ; psi /ft ! Ib /gal ! Caption Contact ft Mud After Lines 0.6% CP_SAP 0.551 10.604 10.604 923.03 3185.95 0.9999 (0.547 to lb /gal 0.554 psi /ft) Mud Column Gradients STD psia Comment Mud After Lines 2.7800 1 1 NICOLAI CREEK NO. 11 6 a Schlumberger pres ■ --. FORMATION (CP_SAP psia) MUD AFTER (CP_SAP psis) 1:3515 ft DRAW DOWN MOBILITY NPOR (v /v) (CP -SAP and /cp) 0 2000 500 2000 TVD VD) 0.6 0 I _ Dry Test GR (gap') 0.1 1000 DPHI (v /v) 0 150 0.6 0 -.1.. 5 8 5 IIM ® S5 v 4 III-7A 900 _=.....- Q 4 m ■t I 10 I \ 111F-1 1000 r Me a 1100 ii �— ■ ■ a 1200 �. �� � mirir .11.7 1300 - -�rgm- 1711 i� � 13 su� .. I 3 1400 � O �, i �� _ �Fi 1500 ,EN 1600 , ia ®9 § ,��' 1700 0- I up 28 ,.11' ` _ ° 6 28 II Ca ' _, RII 0 213b ir' 1800 • iiiim I - - ` 1900 -- = ■►ice ■ Il 2000 ��� ■r i 10.604 ib/ ai ' 1-&-P-1. M 1 0g 1.-... - _ � g� 2100 • '11 0 * 1: order iiE '1'1 2200 U II '� ' ® : 1 604;102 ■ - ,, 2300 ® 9. i j -7 2400 ■■NEMIWI I 2500 a iliffi m 2600 111111:_ 1 0 8 _Ana mi 2700 2800 I 1111111F" ____•,7.4 2900 I l!— I IIj II me -a Phi 3100 IHhI lir mmillmimmill ' - �i ` 3200 I IHI r mi >> 3300 — =� =m I ® _ E3�i 3400 9 • !_7 :71.1■ ill'Ta. I NICOLAI CREEK NO. 11 7 Seblumberger XY MUD Before vs MUD After I 1800.00 , . 2 •8 I # 2 I Mud #1# Pressure After (psia) 1 OM #i8 1 0 7 I I I 530.00 ac I 530.00 Mud Pressure Before (psia) 1800.00 I I I I NICOLAI CREEK NO. 11 8 t I Schlumberger Pressure Gauge Comparison Table I est ' Test T arma tion ' Mud Mud 1 11111 1 1111 TVD Subsea ressure Before € Aiter Test Type (CP SAP) (CP SAP) ` (CP SAP) ; " -90 '1 452.2= 538.46 539.12 Volumetric Limited draw down I M 1 , 111 43 1392 -1372.0i, 737.88 803.8 804481 Volumetric Limited draw down 41 1414 1394 0 0 725.57 816.59 816.111 Volumetric Limited draw down 39 1 -1410 01 681.52 825.891 825.62 Volumetric Limited draw -down 37 't „ 1 432 9 836.69t 837.56 Dry Test a 35i� X1639 "•" 702.671 95423 954.21 Volumetric Limiteddrawdown " " 165 1 00 698 85 962.07 961.63 Volumetric Limited draw down 29 17 1 14 • 996.12 996.11 ` Unrecognizable 31 • 876.66 996.78 997.88 Volumetric Limited draw down 899.06 1013.46 1012.99 Volumetric Limited draw down I l , 908.94 1039.59 1039.21 Volumetric Limited draw down L 23 1828 -1807.9 869.23 1049.721 1048.9' Volumetric Limited draw down 20 2090 -2069.91 997.93 1193.331 1193.04 Volumetric Limited draw down ,, ti 21 i 2099 1,„,,,,,!,47 991.17 1197.87 1197.64 Volumetric Limited draw -down 18 2100 20 pp A 982.21 1198.87 1198.82 Volumetric Limited draw -down r; 16 2260, ; ®' 1110.61 1285.83 1285 33! Volumetric Limited draw -down 14 2 s 1118.751 1293.65 1293.55 Volumetric Limited draw-down r717:7714 13 1294.89 1294.53 Dry Test F. 234'; 1192 1332.42 1332.26 Volumetric Limited draw down I i :" m 1131.371_ 1336.46' 1336.21 Volumetric Limited draw down 1 - ° 1100.98; 1341.95, 1341.8 Volumetric Limited draw -down ' " % 6' 2511 1 4:7;;;I:1?. 1422 84 1422.64 Dry Test 2697 94 1301.51 - 1534.24 1534.2 Volumetric Limited . I V 143714 1436.63 Unrecognizable x"�a etnc Limi draw down I 3160 • 2,: i 1788.051 1787.91 Dry Test ._ 4444: f I -1 41 6 441. � _i 1787 92 1787.41 Dry Test vy 9 3 ':<1:1;111'1,11f: 1791.52 1790.721 Dry Test 37, 2 3 � • 1655.17; 1655.63 1654.89 Volumetric Pretest ����� I Gauge Specifications ; S ems'. "� 4 ' '7 4,7/ : ": 1 ' ° !PI' 1 4� A � s Pressure, -... v,, =�� . Accuracy ' Repeatability ? Resolution Range , Symbol '� ps i) (psi) (psi) ■ si CP_SAP (Strain) 10 - 20000 1+/- 5.0000 +1- 0.5000 0.0400 XPPS I I I I 1 NICOLAI CREEK NO. 11 9 Schlumberger Test Point Table File Test Test Test Test Formation Last -Read Mud Drawdown Test Type Mud Remarks I No. No. TVD MD Subsea Pressure Buildup Before Mobility After ft ft ft psia psia psia and /cp psia 74 43 ' 1392 1392.00 -1372 , 737.88 670.62 803.8 3.45 Volumetric 804.48 Good Limited Radial draw -down Time. Func. but I build down spike, ( QC =7 73 41 1414.01 1414.01 - 1394.01 725.57 708.8 816.59 0.34 Volumetric 816.11 OK Radial Limited Time Func. draw -down QC =7 70 39 1430 1430.00 - 1410 681.52 679.27 825.89 0.61 Volumetric 825.62 Good I L imited Spher.Tim e draw -down Func., QC =10 I 69 37 1452.98 1452.98 - 1432.98 98.97 836.69 Dry Test 837.56 Dry Test 67 35 1659.96 1659.96 - 1639.96 702.67 702.67 954.23 15.75 Volumetric 954.21 Stabilized I L i mi ted press, no draw -down Spher. or Radial Time func. I 66 33 1673 1673.00 -1653 698.85 698.85 962.07 12.5 Volumetric 961.63 Build Up, Limited then down, draw -down QC =7 ..__ 64 29 1734.98 1734.98 - 1714.98 929.67 996.12 Unrecogniz 996.11 Unrecogniz able able 65 31 1736.53 1736.53 - 1716.53 876.66 876.66 996.78 0.12 Volumetric 997.88 Building No Limited timefunc., I draw -down QC =7 63 28 1765.03 1765.03 - 1745.03 899.06 880.51 1013.46 0.35 Volumetric 1012.99 Good Limited Radial Time draw -down Func., Pres building, QC =10 62 26 1810.9 1810.90 - 1790.9 908.94 894.55 1039.59 0.4 Volumetric 1039.21 Good Limited Radial Time draw -down Func., Pres building, I QC =10 61 23 1827.95 1827.95 - 1807.95 869.23 867.82 1049.72 1.71 Volumetric 1048.9 Good Limited Spher. Time i draw -down Func., QC =10 58 20 2089.93 2089.93 - 2069.93 997.93 992.06 1193.33 0.98 Volumetric 1193.04 Good Limited Spher. Time draw -down Func. Press building, QC =10 1 1 NICOLAI CREEK NO. 11 10 I I Test Point Table $chlumberger I Pretes Temp. Packer Time & Pretest t Temp Ti Index Start BU File -ID Probe Date Volume Time After Files me Pres DEGF cc s DEGF psia I 80.83 Convention on 1Sep -200 0.22 0.9 80.86 F74T42T43. 479.31 XPT_074 a t Probe 9 04:35:00 ` as LTP I I 80.69 Convention 14-Sep -200 0.43 1.2 80.81 363.11 XPT_073 al Probe 9 04:16:00 LTP I 80.48 Convention 14-Sep -200 0.35 1.2 80.62 377.7 XPT_070 at Probe 9 04:03:00 LTP I 80.11 Convention 14-Sep -200 1.02 2.7 80.17 IIII. 89.94 XPT_069 al Probe 9 03:56:00 LTP 83.35 Convention 14-Sep -200 0.55 1.5 83.31 F67T34T XPT_067 I al Probe 9 03:27:00 las LTP il . I 83.95 Convention 14-Sep -200 0.16 0.9 83.82 F66T32T 615.6 XPT_066 ii i al Probe 9 03:18:00 LTP I 84.74 Convention 14-Sep -200 0.41 1.5 84.63 764T29.1 380.81 XPT_064 at Probe 9 02:49:00 LTP 84.16 Convention 14-Sep -200 0.27 1.2 84.2 F65T3 564.7 XPT_065 at Probe 9 02:57:00 las LTP I 85.34 Convention 14-Sep-200 0.29 0.9 85.16 F63T27T2' 580.54 ° XPT 063 at Probe 9 02:33:00 LTP I 86.31 Convention 14-Sep -200 0.26 0.9 86.11 624.02 XPT_062 al Probe 9 02:14:00 LTP I _.__.---------- - - - -- 87.35 Convention 14-Sep -200 0.41 1.2 87.17 583.01 XPT_061 at Probe 9 02:04:00 LTP 87.46 Convention 14-Sep -200 0.22 0.9 87.56 777.12 XPT_058 I al Probe 9 01:42:00 LTP I I I NICOLAI CREEK NO. 11 11 Schlumberger 1 Test Point Table File Test Test Test Test Formation Last Read Mud Drawdown Test Type Mud Remarks No. No. TVD MD Subsea Pressure Buildup Before Mobility After ft ft , ft psia psia psia ; and /cp psia 60 21 ' 2098.59 2098.59 - 2078.59 991.17 982.02 1197.87 4.79 r' Volumetric 1197.64 I Good Limited Spher. Time draw down Func., Pres building I down, QC =10 57 18 2099.97 2099.97 - 2079.97 982.21 981.99 1198.87 20.94 Volumetric 1198.82 OK Spher. L imited Time Func. draw -down building Press, QC =10 54 16 2259.98 2259.98 - 2239.98 1110.6 1109.31 1 1285.83 1.17 Volumetric 1285.33 Good L S pher. Time draw down Func. Building Press, QC =10 I 53 14 2273.98 2273.98 - 2253.98 , 1118.75 1117.14 1293.65 0.98 Volumetric 1293.55 Good L S pher. and E draw down Radial Time Func. - building ' 1 I press, QC = I 10 52 13 2275.9 2275.90 - 2255.9 996.28 1294.89 Dry Test 1294.53 Dry Test 50 12 2343.98 2343.98 - 2323.98 1192.89 1196.42 1332.42 0.44 Volumetric 133226 Build up Limited then down, draw -down good spher. Time Func., QC = 10 49 10 2350.96 2350.96 - 2330.96 1131.37 1123.97 1336.46 1.05 Volumetric 1336.21 Building L imi ted press - draw down good Spher. Time func. I QC = 10 48 8 2360.95 2360.95 - 2340.95 1100.98 1096.34 1341.95 0.95 Volumetric 1341.8 Good spher. I Limited and Rad. draw -down Time Func. - building press QC = 10 1 46 6 2510.98 2510.98 - 2490.98 57.64 1422.84 Dry Test 1422.64 Dry Test 45 2 2536 2536.00 -2516 1348.94 1437.14 Unrecogniz 1436.63 Unrecogniz able able 40 4 3180.96 3180.96 - 3160.96 51.66 1788.05 Dry Test 1787.91 Dry Test I 41 6 3180.96 3180.96 - 3160.96 918.95 1787.92 Dry Test 1787.41 Dry Test 39 3 3185.95 3185.95 - 3165.95 _ - 55.59 1791.52 Dry Test 1790.72 Dry Test I NICOLAI CREEK NO. 11 12 I 1 Schlumberger Test Point Table 1 Pretes I 1 T emp. 1 Packer ( Time & j Pretest i t Temp I Time Index Start BUj File : Probe 'Date I Volume' Time j After I Files ' Pres 1 DEGF I I cc S s DEGF 1 psia 87.58 1 Convention 114-Sep-200 0.37 1.2 87.73 1 111 ' i l 794.42 XPT_060 al Probe 9 01:53:00 LTP 1 I I 87.18 Convention 14-Sep -200 1.88 3.9 87.32 874.04 XPT_057 al Probe 9 01:33:00 LTP 1 90.12 Convention 14-Sep -200 0.31 0.9 90.21 54T15T16. XPT 054 al Probe 9 01:05:00 s LTP I 90.11 Convention 14-Sep -200 0.31 0.9 90.17 754.89 XPT_053 al Probe 9 00:57:00 LTP 1 I 90.1 Convention 14-Sep -200 0.78 2.1 90.27 F52T13.1as 705.63 XPT_052 al Probe 9 00:48:00 10 LTP 90.22 Convention 14-Sep -200 0.36 1.2 90.39 F50T11T121 697.98 XPT_050 1 al Probe 9 00:34:00 las LTP _ _ I 90.22 Convention 14-Sep -200 0.34 1.2 90.34 49 10.1 716.82 XPT_049 al Probe 9 00:21:00 s LTP 1 90.33 Convention 14-Sep -200 0.23 0.9 90 37 F48T7T8.la 732.17 XPT_048 1 al Probe 9 00:07:00 s LTP I 1 7 1 1 92.17 Convention 13-Sep -200 5.01 10.5 92.23 F46T3T4T5 52.31 XPT_046 al Probe 9 23:44:00 T6.las LTP 92.57 Convention 13-Se p 200 1.99 4.5 92.82 45T2.Ias 252.92 XPT_045 al Probe 9 23:24:00 I LTP I 97.23 Convention 13- Sep -200 10 21.3 97.3 ; 1F40T4las 48.48 XPT_040 al Probe 9 22:34:00 LTP 97.15 Convention 13-Sep -200 0.43 1.5 97.28 1 F41 T5T6.1a 768.07 XPT_041 I al Probe 9 22:39:00 s LTP I 97.42 I Convention 13- Sep -200 10 21 97.42 F39T3.I XPT_039 al Probe 9 22:26:00 j LTP I 1 NICOLAI CREEK NO. 11 13 Schlumberger 1 Test Point Table File Test Test Test Test Formation Last -Read Mud Drawdown Test Type Mud Remarks 1 No. , No. TVD MD Subsea Pressure Buildup Before Mobility After ft ft ft psia psia psia and /cp psia 1 37 2 3390.97 3390.97 `- 3370.97 1655.17 1654.83 1655.63 14.38 Volumetric = 1654.89 Good Pretest Spher. Time functions, building profile QC 1 10 1 76 45 923.03 923.03 - 903.03 452.2 452.24 538.46 25.03 Volumetric 539.12 Good L S pher.Time draw -down Func., building I Press QC =10 42 8 2717.94 2717.94 - 2697.94 1301.51 1263.27 1534.24 2.08 Volumetric 1534.2 Good 1 Limited Spher. Time draw -down Func., Pres. building down, QC 1 =3 1 1 1 1 1 1 1 1 1 1 NICOLAI CREEK NO. 11 14 1 ' Schlumberger Test Point Table Packer Time & Pretest Temp Time Index Start BU Temp. Pretes Probe Date Volume Time After Files Pres File ID ' DEGF cc s DEGF psia 97.25 Convention 13- Sep -200 9.69 19.8 97.41 F 7 1480.09 XPT_037 al Probe 9 22:02:00 LTP ' 79.77 Convention =.14- Sep -200 1.41 3 79.52 389.16 XPT_076 al Probe 9 04:55:00 LTP ' 95.42 Convention 13-Sep -200 0.47 1.2 95.14 I42T7T8.la XPT_042 al Probe 9 22:59:00 L LTP i ' i i ' i ' NICOLAI CREEK NO. 11 15 Pressure Vs Time Plot : File 37 Test 2 3390.97 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 9 Test 1 Test 2 o m m M 0, T ,� (- • — IIII LL • >- O 0 a' n F a a 0 a d 2 W x a x F (/) 0 w a 2 w a: I- X a a w x O W x cc w > w a _ V) m w Cl- a I— 0O w to CC cc O a U a H a 4 0_ a co m x N p I 0 r 1 LO o I d N O N N N W l 1 O O N A 400 500 600 700 800 900 Detail Pressure Plot Time (sec) Tool Type XPT P • Mud Before Test Type Volumetric Pretest I' D rawdown Start Packer Conventional Probe t 1 r 14 III lit Ili i � ul 1654.83 ,,` i• R, , t �lll �,L Y i J� ■ 1 .. Jill �6 I�: Gauge CP_SAP �MINy Buildup Start Formation Pressure 1655.17 psia `° Last Read 1654.83 psis 0- 1654.63 E Buildup Drawdown Mobility 14.376 and /cp (9.69 cc) 2 : Mud After v 1654.43 Mud Pressure Before 1655.63 psia 2 Mud Pressure After 1654.89 psia n- Temperature Before /After 97.25 DEGF / 97.41 DEGF 1654.23 Pretest RateNolume 0.49 c3 /s / 9.69 cc 1654.03 500 570 640 710 780 850 Good Spher. Time functions, building profile QC 10 Time (sec) 16 OM • NM 1111111 NM UM OM IIM IIIIN MN MI IIIIIII MN IIIIIII UM N 1 Mili MN 11.1 I 111. IMO UM Mil MIN Mil I EN MIN MB OM S MIN 1=1 MIN Flow Regime Identification Plot : File 37 Test 2 3390.97 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Spherical Time Function Plot : 1e+05- _ . -, I - 1800 0 Spherical Derivative - -- f - - • I I _ 0 Radial Derivative ' 4 i I O 1700 CO ❑ 'm Q 1e +02 _ .� i 2 o u 0 .� - L .J a) ��� `J4j s ;: .. �_ 1479 ♦ �iI ♦: / :♦%;.✓ 1.6 1.000 0 m IA 1 ; i j - Spherical Time, 1 /sqrt(sec) d _ • /111 .. _ i Last Buildup Pressure : 1654.83 psia r:;:1 ' Extrapolated Pressure : 1655.17 psia _ Buildup Mobility : 5.98 and /cp L - f - it Spherical Slope : -12.68 in 1e +OC . _ . Radial Time Function Plot 1800 1e-01 1e +00 1e +01 1e +02 . CTS Delta-Time (sec) Slope on Spherical 0.043 d O O Slope on Radial - 0.466 0 2 1600 U) U) d 0 1400, 1.8 1 0 Radial Time Last Buildup Pressure : 1654.83 psia Extrapolated Pressure : psia Horiz. Mobility Thickness : md.ft/Cp 17 Pressure Vs Time Plot : File 39 Test 3 3185.95 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 O O 0 O O O 0 0 N N . In I � W y O. lL ❑ U w 2� m ❑ a a a 0 0. F 2 d 1 d co x a X \----._ Fw- CO U W r E • a x a > - • W a x ci N W - a w a < W w CO K ▪ 0 cc 0 1 a f = 1- a a a a y (/) x m O C ❑ M - o "---- (_ N V O O a, O O .-- A I 100 200 300 Time (sec) Tool Type XPT • Mud Before Test Type Dry Test Packer Conventional Probe X Drawdown Start Gauge CP_SAP Buildup Start Formation Pressure psia El End Buildup Last Read 55.59 Asia El Mud After Mud Pressure Before 1791.52 psia Mud Pressure After 1790.72 psia Temperature Before /After 97.42 DEGF / 97.42 DEGF Pretest RateNolume 0.48 c3 /s / 10 cc Dry Test 18 • • • 1.0 • • IMO • ONI • 1.1 • I• MIN ONN INI M 11=1 • NM OM N I I I • NM MI I♦ 11110 • N • IIIII • OM MI IMI Pressure Vs Time Plot : File 40 Test 4 3180.96 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 a a ' q 0 o a 0 o a 0 0 N N W LL ❑ U O d a 1- - n d U d X a X S W W U W a 0 • x a a x n x co w a a fi r _._. .._ cc ce • O z U a 1 a ¢ Q X a 0) co U re o } 2 0 0 - 0 - 0 v o O o rn o o A 100 200 Time (sec) Tool Type XPT • Mud Before Test Type Dry Test Packer Conventional Probe Drawdown Start Gauge CP_SAP Buildup Start Formation Pressure psia In End Buildup Last Read 51.66 psia • Mud After Mud Pressure Before 1788.05 psia Mud Pressure After 1787.91 psia Temperature Before /After 97.23 DEGF / 97.3 DEGF Pretest RateNolume 0.47 c3 /s / 10 cc Dry Test 19 Pressure Vs Time Plot : File 41 Test 6 3180.96 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 Test 5 Test 6 0 0 0 0 0 0 o 0 0 0 N N LL 0 - Q a = w x a_ x F N U w a 2 w cC • X a 0_ w x F ▪ 0 w m • O o U a ▪ a ¢ a X ¢ N N 0 0 } I u> 0 - o 0 o o a m � ^-� o o I l O o o o "'� I I 100 200 300 400 500 600 700 Time (sec) Tool Type XPT Mud Before Test Type Dry Test Packer Conventional Probe Q Drawdown Start Gauge CP_SAP 0 Buildup Start Formation Pressure psia • End Buildup Last Read 918.95 psia ▪ Mud After Mud Pressure Before 1787.92 psia Mud Pressure After 1787.41 psia Temperature Before /After 97.15 DEGF / 97.28 DEGF Pretest RateNolume 0.29 c3 /s / 0.43 cc Dry Test 20 MI • M MI IMO IMII • MI IIIIII I= I— MI NM UM I INIII IMI MN -" Pressure Vs Time Plot : File 42 Test 8 2717.94 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 1 Test 7 Q Test 8 O 0 0 O 0 0 0 0 0 - 0 0 N N II, ._._. N . a LL 0 7 U W • x w v o a N y N ~ 2 0. X al ( 1[ U t,/ w • a f 2 a J X X o a' CO o> a a x w U) w a a w o - U a A a a Q a a N x re 0 u> o ' 0 o_ v o o o o o o A I\ n 100 200 300 400 500 1266.27 Detail Pressure Plot Time (sec) Tool Type XPT MI Mud Before Test Type Volumetric Limited draw -down Drawdown Start Packer Conventional Probe X 1264.27 Gauge CP_SAP _ Buildup start Formation Pressure 1301.51 psia m \.. Last Read 1263.27 psia 21262.27 End Buildu Drawdown Mobility 2.081 and /cp (0.47 cc) E. • Mud After ' „ 1 260.27 Mud Pressure Before 1534.24 psia E Q Mud Pressure After 1534.2 psia o_ Temperature Before /After 95.42 DEGF / 95.14 DEGF 1258.27 Pretest RateNolume 0.4 c3 /s / 0.47 cc 1256.27 G ood Spher. Time Func. - but press. building 253.6 291.08 328.56 366.04 403.52 P 9 down: QC =3 Time (sec) 21 Flow Regime Identification Plot : File 42 Test 8 2717.94 ft (TVD) Schlumberger 11 Spherical Time Function Plot : 1e +04 I NICOLAI CREEK NO. 1 2000 Spherical Derivative _ - -- • ❑ Radial Derivative _ r •1* N 1e +0o ca • 6 1 e +O2 ca 1400 0 rn 1e +01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical -0.009 Slope on Radial -0.450 '1 0 0 0 0 758 '1 0.600 0 Spherical Time, 1/sqrt(sec) Last Buildup Pressure : 1263.27 psia Extrapolated Pressure : 1301.51 psia Buildup Mobility : 0.22 and /cp Spherical Slope : - 1487.71 22 — • — I_ NM • • NM • • • UM I UM IIMI MI 11.1 • 111. NIIM 1.0 IIIM • Pressure Vs Time Plot • File 42 Test 8 2717.94 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 7 U Test 8 0 0 0 0 of ri o e e m m 7 m n LL ❑ M U 0 a n a X a I X IL u � 0 J w a M x a a w x o o x w > w a x (1) w a a - I- 0 w U7 it O a: 0Y I EL ¢ Q a . X g O 0 O o ❑ x 2 un o 0 0 c e e 0 0 ° 0 0 rn r- N i 240 250 260 270 280 290 300 310 320 Time (sec) Tool Type XPT ▪ Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe V Drawdown Start Gauge CP_SAP A Buildup Start Formation Pressure 1301.51 psia ▪ End Buildup Last Read 1263.27 psia Drawdown Mobility 2.081 and /cp (0.47 cc) ▪ Mud After Mud Pressure Before 1534.24 psia Mud Pressure After 1534.2 psia Temperature Before /After 95.42 DEGF / 95.14 DEGF Pretest Rate/Volume 0.4 c3 /s / 0.47 cc Good Spher. Time Func. - but press. building down: QC =3 23 Pressure Vs Time Plot : File 45 Test 2 2536.00 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 1 Test 2 � v �o Ili i °- a v 1 . (n N o ffl j CQ W F 2 w W 0 i t U a _ _.._._. F CL a a a X Q N to — - N O Ce O S Ll N O; h �y c (�'� I O ; O O ! I 1 1 1 1 1 -, I 1 A "1 • I 100 200 300 400 500 600 700 800 900 Time (sec) Tool Type XPT • Mud Before Test Type Unrecognizable Packer Conventional Probe v Drawdown Start Gauge CP_SAP 0 Buildup Start Formation Pressure psia • End Buildup Last Read 1348.94 psia • Mud After Mud Pressure Before 1437.14 psia Mud Pressure After 1436.63 psia Temperature Before /After 92.57 DEGF / 92.82 DEGF Pretest RateNolume 0.44 c3 /s / 1.99 cc nr niz U ecog ab le 24 NM — • • — I — • I= MI MIN • I• — — MI — • MI • NM IIIIII MI • IMIN UM 111. • INI II= UM II. NM ill. .1111 I= MI IIIIII Flow Regime Identification Plot : File 45 Test 2 2536.00 ft (TVD) Schlumberger 1e +0' NICOLAI CREEK NO. 11 0 • Spherical Derivative - ■■..MIII■■___■ - _ N - ■ 0 Radial Derivative 1e +1 r I .____■■■........ •�. ∎Nroz .. an ∎___■..■I 1111111 P Ell col e +0 .......... .ww •.�•.a____ it _ ■� ∎� ■=m... I■ U i a .111 eirm cn cn e +o. 111111 g`4III!,' �i 11111_11111111 mil ...•�iw� i. rte..■. ������.o==esi�.o ��� ■ ■ ■ ■ ■�t��r �1 ■ ■ ■ ■:1�_ � 7�� ■ ■ ■ ■••�� ■ ■ ■ ■•1 w•iiiiiliink=4III! i aliiiIII-•■111111 irrivinul +0_ iI• •=mm∎∎mimwiIIII..■■_1Iloo ii■flIIIIMIIIMM ■ONIIII■MM M! i■ flMNIIM.N■111■MMIIIMINMEN I■ 1e +11 1e +00 1 e +01 1e +02 Delta -Time (sec) 25 Pressure Vs Time Plot : File 46 Test 6 2510.98 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 3 Test 4 I Test 5 Test 6 0 0 0 LO 0 0 rn o 0 N 0 N W a M LL U 9. • al n n d U a a a H . d >,,, a X =, F U U w • a 2 w X CC a W x U L1J x ,C W m w a a w I- p w W 1 a a a ° x a m o W O 6 o 0 0 o 6 o o n h 100 200 300 400 60.64 Detail Pressure Plot Time (sec) Tool Type XPT Mud Before Test Type Dry Test V Drawdown Start Packer Conventional Probe 58.64 Gauge CP A Buildup Start Formation Pressure psia m 856.64 El End Buildup Last Read 57.64 psia N MI Mud After Mud Pressure Before 1422.84 psia v Mud Pressure After 1422.64 psia 54.64 Temperature Before /After 92.17 DEGF / 92.23 DEGF a Pretest Rate/Volume 0.48 c3 /s / 5.01 cc 52.64 A 50.64 355.3 368.04 380.78 393.52 406.26 Time (sec) 26 III. I=1 — NM — OM NM MI — — • • — OM IM OM MI On NS 1111111 IIIIII NM • 111. IIMO • • Flow Regime Identification Plot : File 46 Test 6 2510.98 ft (TVD) Schlumberger 1e +o° NICOLAI CREEK NO. 11 _ 0 Spherical Derivative -- - — O Radial Derivative 1e+02 .- ' . �I •■• i>3 •: • .* • i O1 e +01 _ .ioi - -•� • • a •4 • ♦ X 1 0 iii • • 1 e +OC .1- i■ ❑ gin O 1e -01 1e +00 1e +01 Delta -Time (sec) 27 Pressure Vs Time Plot : File 48 Test 8 2360.95 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 9 Test 7 V Test 8 0 0 0 0 0 rn o 0 u N c•-•;' LL 0 U p =I y > a a a a v N F a_ ,i \*',; ( 7—r------ iii CI- S w U W a E w ' Pr_ a > w a = I�.".. . a 2 a a a- X a Co o } 2 o 0 0 0 u- I v 0 0 0 0 0 o o rn o O 100 200 300 400 500 600 700 1110 Detail Pressure Plot Time (sec) Tool Type XPT Mud Before Test Type Volumetric Limited draw -down 1100 / V Drawdown Start Packer Conventional Probe _ - Gauge CP_SAP To 100.98 psia 01090 II End Buildup Last Read 1096.34 psia E / Mud After Drawdown Mobility 0.951 and /cp (0.23 cc) tL Before 1080 Mud Pressure After 1341.8 psia 'a Temperature Before /After 90.33 DEGF / 90.37 DEGF 1070 Pretest RateNolume 0.25 c3 /s / 0.23 cc 1060 390 400 410 420 430 440 Good spher. and Rad. Time Func. - building press QC = 10 Time (sec) 28 M NM NM MN — Me — — • NM NM NM NM NM — MN — MN NM • NM MN MI NM MN 1111. NM MI NM INO IIM Mil MI 611. MIN IIM IIIM Flow Regime Identification Plot : File 48 Test 8 2360.95 ft (TVD) Schlumberger NICOLAI CREEK 1e +o t Spherical Time Function Plot : _ a_ _ 2000 • Spherical Derivative ■N 0 Radial Derivative — • 111 a N 1e +04 __ ' `� 0 1400 > y am, u) �� � it is �� ` 1 1+0 0 0 0 ■ 731 • � - 0 ■ 0.91 0.500 O� 1,_ Spherical Time, 1 /sqrt(sec) 0 I FIT Last Buildup Pressure 1096.34 psia • se Extrapolated Pressure 1113.06 psia _. g, _ i = _ Buildup Mobility 0.11 and /cp Spherical Slope : - 2588.84 1e +02 1e +00 1e +01 1e +02 Delta-Time (sec) Slope on Spherical 0.005 ( ) Slope on Radial -0.460 Radial Time Function Plot Slope on Spherical 0.525 2000 Slope on Radial -0.002 1 tb J i000 _ [0 0 p0 0 0.6 0.4 0 Radial Time Last Buildup Pressure : 1096.34 psia Extrapolated Pressure : 1100.98 psia Horiz. Mobility Thickness : 0.068 md.ft/Cp Radial Slope : - 331.53 29 Pressure Vs Time Plot : File 49 Test 10 2350.96 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 g 1 Test 9 Q Test 10 0 0 0 0 0 m o 0 0 0 m r 1 (...mi ir •••■•■•■111M■111111.11■1111M w 1 n U w 2 m a o a a F � a o a Q H M al X a X . 1- rn 0 w ▪ d 2 w S a a X w x > E X 1 w Q I-- r w a a U. 0 w W K a 2 a Q Q I \\ m X N rn _ - - - - - c ( i ) 0 .I M I i 0 0 - - 0 0 ,r 0 0 0 a r o rn 0 0 100 200 300 400 500 600 1200 Detail Pressure Plot Time (sec) Tool Type XPT . Mud Before Test Type Volumetric Limited draw -down 1080 V Drawdown Sta Packer Conventional Probe Gauge CP_SAP Fi A Buildup Start Formation Pressure 1131.37 psia 0- 960 • End Buildup Last Read 1123.97 psia 2 • Mud After Drawdown Mobility 1.053 and /cp (0.34 cc) 2 840 Mud Pressure After 1336.21 psia a Temperature Before /After 90.22 DEGF / 90.34 DEGF 720 Pretest Rate/Volume 0.28 c3 /s / 0.34 cc 600 220 232 244 256 268 280 Building press - good Spher. Time func. QC = 10 Time (sec) 30 MINI Elli — NM • IIIIII • NM MN 111. MB MI Me MI MIII MI — MI Flow Regime Identification Plot : File 49 Test 10 2350.96 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Spherical Time Function Plot : 1e +04 ' ' -- 2000 HO Spherical Derivative - - ❑ Radial Derivative 1 -ii 1 :: 1 ■■1 1 ■11 IIIIMIMPIIIIIIIIIIM1 1 III 0> := - ..- ..=ii •@ �_1 '� ■• ■■ 02 1 • • • ■ 16171111111 ilk'. co co IL 1e +0,. ■ -■■ - I 1111111. -' 1�.Ii. -.� � 1 N1_- .ni400 0) L N 0) 1e +01 d 1e +00 1e +01 1e +02 Delta-Time (sec) Slope on Spherical 0.002 ( ) Slope on Radial -0.460 al • O O O� 716 1 0.600 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 1123.97 psia Extrapolated Pressure : 1131.37 psia Buildup Mobility : 0.14 and /cp Spherical Slope : - 2045.96 31 Pressure Vs Time Plot : File 49 Test 10 2350.96 ft (TVD) Schiumber NICOLAI CREEK NO. 11 ger 0 ^ Test 10 n r- O N i0 W L1 R LL 0 O w 2 0 a v L a • v < < Go 1— 2 al 9<- LI X I- W 0 W I- --- �� f L a L W X > u X L�J > u a = c ~ N w 0 L W H 0 H C W W a O = L 2 21: < L 1- x m w 0 r = 0 o ai O o rn l 220 230 240 250 260 270 280 290 300 310 320 330 340 350 360 370 Detail Pressure Plot Time (sec) Tool Type YPe XPT • Mud Before Test Type Volumetric Limited draw -down Drawdown Start Packer Conventional Probe 1124.97 Gauge CP i V Buildup Start Formation Pressure 1131.37 psis 0 1122.97 / End Buildup Last Read 1123.97 psis Drawdown Mobility 1.053 and /cp (0.34 cc) Mud After D 21120.97 Mud Pressure After 1336.21 1336.21 psia Temperature Before /After 90.22 DEGF / 90.34 DEGF 1118.97 I Pretest RateNolume 0.28 c3 /s / 0.34 cc 1116.97 226 293.6 361.2 428.8 496.4 Building press - good Spher. Time func. QC = 10 Time (sec) 32 MI MIll 111. MN 1.11 IIIIIII NM IRO NM NIM 1.111 MOI IMI MO II•11 ON MI IIMI 11.1 MIII OM MI OM I♦ = MI 11111 MN = NM MI MI MN MI IMMI 111. IMI UM Pressure Vs Time Plot : File 50 Test 12 2343.98 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 11 [ Test 12 o 9 e CIF ag N a` 7 :E- .. m u- o U W = 2 a a a U d y y F V H d a 1 X . F Cl) ( w a 2 w D • x a n o a X d > w a = LL ti) W w a n w O i x U 5 X Q M V W 0 , 0 } 1 0 0 00 A o e 0 0 0 , O 0 c 230 240 250 260 270 280 Detail Pressure Plot Time (sec) Tool Type XPT 1199.42 III Mud Before T Type Volumetric Limited draw -down Packer Conventional Probe Drawdown Start 1197.42 Gauge CP_SAP Buildup Start Formation Pressure 1192.89 psis Last Read 1196.42 psia 0- 1195.42 End Buildup Drawdown Mobility 0.439 and /cp (0.36 cc) a) ® Mud After m 21193.42 Mud Pressure Before 1332.42 psia Mud Pressure After 1332.26 psia a` Temperature Before /After 90.22 DEGF / 90.39 DEGF 1191.42 Pretest RateNolume 0.3 c3 /s / 0.36 cc 1189.42 1 241.6 317.68 393.76 469.84 545.92 622 Build up then down, good spher. Time Func., QC = 10 Time (sec) 33 Flow Regime Identification Plot : File 50 Test 12 2343.98 ft (TVD) Schlumberger 1e +0 NICOLAI CREEK NO . 11 Spherical Time Function Plot : N om mw ' 2000 Sp herical edvativ e Live ❑ Radial D ,J= - , ., . erivativ_ ■111111 I All II le+0 • 111 _poi 11 11111 !!'AINiCIMIIu 0 1111111 W41 IIIIk 1 u h.5 1111,0.41110111 III p 1e +0 L I ... 1e +02 Q d u • • II ■ ...uIll 11 , _ MO 1 I 1e +01' 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.027 Slope on Radial -0.455 Sr lbo o • 0 0 O 697\ 1 0.600 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 1196.42 psia Extrapolated Pressure : 1192.89 psia Buildup Mobility : 0.07 and /cp Spherical Slope : - 6627.6 34 MN MI IIMI • OM = MI I= MN MN NM • IMI 1.11 MI 1.11111 • • MI I• NM NM MI — — UM IIIIM = MI Ill. MO — N i MN ' — M Pressure Vs Time Plot : File 52 Test 13 2275.90 ft (TVD) Schiumberger NICOLAI CREEK NO. 11 O 0 0 V • O O - f– ie a LL 0 U 0 2 m O a n F n a v a Q IL g 1- 2 a X 0_1 X 1 - W U L11 a 2 2 x a a ' O x c u) > OW a = • 0 co w a a y L1.1 0 w N LU I a g a ▪ F N I ■ r .. X < I 11 re 1 O O v 0 LL's , r o 0 0 0 O O r 0 o m o o A 100 200 300 400 Time (sec) Tool Type XPT • Mud Before Test Type Dry Test 1710 Detail Pressure Plot Packer Conventional Probe V Drawdown Start Gauge CP 0 Buildup Start Formation Pressure psia 1491.2 T . End Buildup Last Read 996.28 psia m • Mud After Mud Pressure Before 1294.89 psia 0-1272.4 Mud Pressure After 1294.53 psia N Temperature Before /After 90.1 DEGF / 90.27 DEGF g31053.6 Pretest RateNolume 0.37 c3 /s / 0.78 cc N a` 834.8 • Dry Test 61 200 245 290 335 380 425 Time (sec) 35 Flow Regime Identification Plot : File 52 Test 13 2275.90 ft (TVD) Schlumberger 1e +r NICOLAI CREEK NO. 11 Spherical Derivative - - - - O Radial Denvative - 1e +0 [ II 1e +0 a) > 0 t III le +0 ti ' 1e +0 : _ - • �a . ■ 1 111 1o 1e +01 le +00 1e +01 le +02 Delta -Time (sec) 36 I= I • — — MO • • OM • • • — • • — • • • MINI • IIMII EN I♦ MIN NM M = • NM NM SEN OM UM 111111 IM MI • Pressure Vs Time Plot : File 53 Test 14 2273.98 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 rn O 0) I � I / D 1 m p W 2 m •o ❑ al n H b a p ii a g iL Ni IL M Cl_ x a X =, F U) 0 w a 2 w • x ' a a O o x re (0 > w a x N CO w a a w F • p ).- C w H K 0 2 a = a a a a a (17) x u) p oCC 2 Il ,1 1 I N O �I O O I N O O O O O I O O o O O 100 200 300 Time (sec) Tool Type XPT II Mud Before Test Type Volumetric Limited draw -down 1200 Detail Pressure Plot V Drawdown Start Packer on _SAP Conventional Probe Gauge C A Buildup Start Formation Pressure 1118.75 psia 1092 V 1 End Buildup Last Read 1117.14 psia Drawdown Mobility 0.977 and /cp (0.31 cc) m 1 Mud After co 984 Mud Pressure Before 1293.65 psia E Mud Pressure After 1293.55 psia gi 876 Temperature Before /After 90.11 DEGF / 90.17 DEGF E Pretest RateNolume 0.34 c3 /s / 0.31 cc a` 768 • 660 Good Spher. and Radial Time Func. - building press, QC = 10 50 64 78 92 106 120 Time (sec) 37 Flow Regime Identification Plot : File 53 Test 14 2273.98 ft (TVD) Schlumberger 1e +oa NICOLAI CREEK NO. 11 Spherical Time Function Plot : n. . - 1 2000 0 Spherical Derivative �� - -- i - , -- _ -- - -- -. 0 Radial Derivative =NM - ■ l_ = M■■= �; 1F, to " / /- > • � .., p 1e +0 a , �� r - 7 N 1400 2 ' ♦ 1 CO co (1) `� `� � liiiL 1 ii — , • O �_ _. 1e +02 1e +00 1e +01 1e +02 O 0 0 754 Delta -Time (sec) Slope on Spherical 0.015 0.91 Slope on Radial - 0.459 0.500 0 Slope on Spherical 0.458 Slope on Radial -0.044 Spherical Time, 1 /sgrt(sec) Last Buildup Pressure : 1117.14 psia Extrapolated Pressure : 1118.96 psia Buildup Mobility : 0.14 and /cp Spherical Slope : - 2455.81 Radial Time Function Plot 2000 0) eL 2loon ∎rrt O O ° 0 • lo w. , • a 0 0.6 0.4 0 Radial Time Last Buildup Pressure : 1117.14 psia Extrapolated Pressure : 1118.75 psia Horiz. Mobility Thickness : 0.053 md.ft/Cp Radial Slope : - 567.75 38 NM I• MN MI NM NM • MI MI 111111 NM ✓• • M 111. MO MI NM MI — MO MN • NM MN I INN NM NM NM MI UM MI 111. IMI Pressure Vs Time Plot : File 54 Test 16 2259.98 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 15 11 Test 16 M M 0, N m m ■ N y a LL 0 M U o a a H n a 0 a a 2 0. a- a X ▪ i w w O w a CC I- • X a a d w x o x 1 W > w a x w (0 w a a < w F o ~ CO CC w ~ O x U a X a 0) y O K i 0 } x 1 - 0 O N ' V V V V .- N Il 1 1 O o c0 f� r 400 500 600 700 Detail Pressure Plot Time (sec) Tool Type XPT 1 1 • Mud Before Test Type Volumetric Limited draw -down Drawdown start Packer Conventional Probe 1109.31 Gauge CP_SAP @ `` 0 Buildup Start Formation Pressure 1110.6 psis I End Buildup Last Read 1109.31 psia 21109.11 Drawdown Mobility 1.165 and /cp (0.31 cc) a. ® Mud After Mud Pressure Before 1285.83 psia E 1108.91 Olr'' Mud Pressure After 1285.33 psia a Temperature Before /After 90.12 DEGF / 90.21 DEGF 1108.71 Pretest Rate/Volume 0.35 c3 /s / 0.31 cc ii, 1108.51 G ood Spher. Time Func. Building 465 530 595 660 725 9 Press, QC =10 Time (sec) 39 Flow Regime Identification Plot : File 54 Test 16 2259.98 ft (TVD) Schlumberger 1e +04 NICOLAI CREEK NO. 11 Spherical Time Function Plot : h 2000 Spherical Deriva - _ ❑Radial Derivative -- ' - - - -- � - i II_ MEN 4 III " sj • 0, 1 e+0".: ∎ �• �� i ..l it •A i �::M7.,� ■� 1 I : �� • .;ii -.!I_9 tr) 0 • . Illiy■ N I. a _ 1 e +02 , - i Q N 1400 Lii. co V) i ilI CL 10 +01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.019 Slope on Radial -0.457 i n k S Mx 0 O 0.O 780 0.91 0.500 0 Spherical Time, 1/sqrt(sec) Last Buildup Pressure : 1109.31 psia Extrapolated Pressure : 1110.6 psia Buildup Mobility : 0.16 and /cp Spherical Slope : - 2014.65 40 — MIMI MO IIM Mli 1 1 Pressure Vs Time Plot : File 57 Test 18 2099.97 ft (TVD) Schiumberger NICOLAI CREEK NO. 11 Test 17 Test 18 o m 9 I m n LL 0 F 2 LL X d l x F W 0 w a 2 ' - x Q a a x r' w > o x 1 w __ _. T I.! > a 2 W 0. N w a a I- ijH X 0 tt 0 } 2 I I o v o0 o 00 n 03 03 200 300 400 Detail Pressure Plot Time (sec) Tool Type XPT ' • Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe 981.99 t X Drawdown Start Gauge CP_SAP _ Q Buildup Start Formation Pressure CPS psia ►� @ I h i�V �'I 1 � p �'I�' Y Last Read 981.99 psis 11 / End Buildup 3981 ' Drawdown Mobility 20.941 and /cp (1.88 cc) N / Mud After '„ Mud Pressure Before 1198.87 psia 981.59 1 Mud Pressure After 1198.82 psia a ` Temperature Before /After 87.18 DEGF / 87.32 DEGF 981.39 h 4' Pretest RateNolume 0.48 c3 /s / 1.88 cc 981.19 h 225 265 305 345 385 425 OK Spher. Time Func. building Press, QC =10 Time (sec) 41 Flow Regime Identification Plot : File 57 Test 18 2099.97 ft (TVD) Schlumberger 1e +0 � , NO. p _spheric- I - NICOLAIN CREEK No 11 Spherical Time Function Plot : • II De - ■ ■ ■� � MIME � M_ . __ �� 1100 El Radial Derivative � ■ ■111 ■_ , , MIEN 1 ■■■IIIII IN . •■I ■II .. 11111 11 111 1e +0" u ■ +1[1.4 , ' ' '� > • I91 A 4 . ' ' - MI p 1e +01 _4 _ y •UUUULI l�J ∎■�MONE 131000 N -.■ __ I I OIIL; r' , N d • ■i11 - 1 • !IIIIiI ■III O 1e -01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical -0.084 Slope on Radial -0.541 873 1.3 0.700 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 981.99 psia Extrapolated Pressure : 982.21 psia Buildup Mobility : 3.27 and /cp Spherical Slope : -30.94 42 i i i i i i i • 111111 i i i i • • i • • • INE 1•10 IMO IIMI INO ONN NM NM 111111 MI UM MI IMMI ail ININ 111111 MI NE MN Pressure Vs Time Plot . File 58 Test 20 2089.93 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 19 11 Test 20 q o s o a a m m x o c V - qi LL M u W = R > a 0 a a v a 1 co (0 d v l a x a K = F co c u r 2 w ' 5 X .._._. I o a w ':: `rte O w x > w a = & - a a L 0 LL L 0 tY — 2 Y L 2 d F Q K a ' v; K y o • o o — o o / ; N c, 0 a0 C o O c r- r. A 250 260 270 280 290 300 310 320 330 340 350 360 Detail Pressure Plot Time (sec) Tool Type XPT ja ! ill r 1 NM= • Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe 992.06 liffi ai ill " Drawdown Start Gauge CP 0 Buildup Start Formation Pressure 997.93 psia Last Read 992.06 psia 8991.86 End Buildup Drawdown Mobility 0.975 and /cp (0.22 cc) II N . Mud After 2991.66 Mud Pressure Before 1193.33 psia N Mud Pressure After 1193.04 psia o_ Temperature Before /After 87.46 DEGF / 87.56 DEGF 991.46 Pretest RateNolume 0.24 c3 /s / 0.22 cc 991.26 G ood Spher. Time Func. Press building, QC =10 250 295 340 385 430 475 9' Time (sec) 43 Flow Regime Identification Plot : File 58 Test 20 2089.93 ft (TVD) Schlumberger ,e +04 NICOLAI CREEK NO. 11 Spherical Time Function Plot : 0 Spherical Derivative • - - - -- -_ -- 1100 0 Radial Derivative IP ■ ■111 ■I■ .re: ■■11111 ■r . e— !!I 1000 co IPO , _ A p le +02 41 • 7 • 7 _ , • ni cn a- ■ ■� 4. u ' or 1e +01 "Id 4 ! . I ; I �ti • 1e +OG 1e +00 1e +01 1e +02 Ov Delta -Time (sec) Slope on Spherical 0.020 0 Slope on Radial -0.458 0 0 0 776 , 0.91 0.500 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 992.06 psia Extrapolated Pressure : 997.93 psia Buildup Mobility : 0.1 and /cp Spherical Slope : - 2884.33 44 ■ • ■ ■ • ■ • ■ ■ • ■ INII MN • • • ■ I■ • MN MN OM MN • NM N • I 111111 MI I M E Pressure Vs Time Plot : File 60 Test 21 2098.59 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 o O 0 0 0 0 0) o) m CO m n LL 0 U w = 0 n H a Q 0 LL a 0 a wi IL = a X a X F W • X a a O w X W X � w > w 0 = w w a a ¢ w F O w o K O U a F a a f- a 0. u) X ¢ O 0 Y 2 o N 0) 0) V ( � O O LL L() O O ap O) Q) 110 120 Time (sec) Tool Type XPT Mud Before Test Type Volumetric Limited draw -down Detail Pressure Plot Packer Conventional Probe 1012 0 Drawdown Start Gauge CP Buildup Start Formation Pressure 991.17 psia 961.6 • End Buildup Last Read 982.02 psia Drawdown Mobility 4.793 and /cp (0.37 cc) Mud After 8911.2 Mud Pressure Before 1197.87 psia Mud Pressure After 1197.64 psia 2860.8 Temperature Before /After 87.58 DEGF / 87.73 DEGF Pretest Rate/Volume 0.31 c3 /s / 0.37 cc 810.4 Good Spher. Time Func., Pres building down, QC =10 760 75 125 175 225 275 325 Time (sec) 45 Flow Regime Identification Plot : File 60 Test 21 2098.59 ft (TVD) Schlumberger 1e +0� NICOLAI CREEK NO. 11 Spherical Time Function Plot : I _ !-- ■ I , 1100 i _ Spherical Derivative - - =mow - _ ❑ Radial Derivative ■=lIM■■NE f -- NM= 6� MENEM EIIIIIIM.. '' • iii "1 � l:tr -; i, . Eller 1 _ 11111 .. .�— _ - . � wm=m_ . =mum ���■ ■ ■ ■ — ■- 4,•i _ _ ■ ■_ __ ■ ■ ■■■ ■-- ,!• ■.■■ _. ■■■uI_MI■ - } let .` ! ■■■■ •■■N111 MEW _ • . _ UM 1000 a 1e+01 li __ ■ ■■ ■� -- U) � �■■■ : MIN .: a ME■ . ' ME■I nil — — g i . I. 1e +OC 11"I •. CL 0 o 0 le-01 1e +00 1 +01 le+02 0 Delta -Time (sec) Slope on Spherical -0.013 Slope on Radial -0.454 793 1 0.600 0 Spherical Time, 1/sqrt(sec) Last Buildup Pressure : 982.02 psia Extrapolated Pressure : 991.17 psia Buildup Mobility : 0.43 nx1 /cp Spherical Slope : -419.77 46 MN • MI MI • MI MI MII MI OINI • 111. MI = • MIN MI • MO • IIM NM MN MN NM NM MI • INE MI MI INIII MB IIM MN • Pressure Vs Time Plot : File 61 Test 23 1827.95 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 22 11 Test 23 o M M O N N 0 o 0 0 0 11 — V f u- 0 M '- t L I I n 5 EL a 0 a a = wl X a X . F C0 O w a 2 w M X d a . o ~ a X w _.. _... O w X cn > w a = i t ci a a a w [t 1- ¢ w ... I- O w N a w ix O O a a a a a a a ' u) X y O 3 in 2 o A v o 0 N O co co N N O O N co M O I j{1 O co dD 10 200 300 400 923 Detail Pressure P lo t Time (sec) Tool Type XPT II Mud Befor Test Type Volumetric Limited draw -down 0 Drawdown Start t Packer Conventional Probe X 841 Gauge CP �° Buildup Start Formation Pressure 869.23 psia Last Read 867.82 psia 0759 End Buildup Drawdown Mobility 1.713 and /cp (0.41 cc) • Mud After 2677 Mud Pressure Before 1049.72 psia N Mud Pressure After 1048.9 psia o_ Temperature Before /After 87.35 DEGF / 87.17 DEGF 595 Pretest Rate/Volume 0.34 c3 /s / 0.41 cc 51 200 250 300 350 400 450 Good Spher. Time Func., QC =10 Time (sec) 47 Flow Regime Identification Plot : File 61 Test 23 1827.95 ft (TVD) Schlumberger 1e +04 NICOLAI CREEK NO. 11 Spherical Time Function Plot : I — Spherical Derivative ' - - . . - - - -- - 1000 O Radial Derivative • ■ f I_ I I IP , ., , , , , , r - , 1e+0.7, �� /� — _� -....i ' .,, . O : 11 - ' fir:. i>. • 4,,.....: , . O6 ■ I ii __ �. i CO i p • "800 • C.V.I. cn co d 1e +01 �. 1 1 d is ' r N Al ❑ 0 1e +OC O 0 0 0 1e -01 1e+00 1e +01 1e +02 Slope on Spherical -0.009 582 Delta -Time (sec) Slope on Radial - 0.471 1 0.600 0 Spherical Time, 1 /sgrt(sec) Last Buildup Pressure : 867.82 psia Extrapolated Pressure : 869.23 psia Buildup Mobility : 0.2 and /cp Spherical Slope : - 1428.23 48 IIIIII • MI • ONII 111.111 • • IIM O11111 1111. 111111 MI • 111. IM 111. IIIIII MI IM NM MI • MI MN MI 1111. • Mille MS NM MI INN — • NM I MI Pressure Vs Time Plot : File 62 Test 26 1810.90 ft (TVD) Schiumberger NICOLAI CREEK NO. 11 24 Test 25 Test 26 o m ao 0) : N ; O) CO V lC N d LL of U i 0 ' .: d 6 F a a. , a a 2 w X d X • H a) 0 w ~ 2 w ` X d d X d 0 X ' ', `&' 1 ,� w > w a i O W w IL d w U a_ • I- a 2 a X o_ N N O Y 2 i A - 0 Ti o 0 In c eo ao o p 0 o vi o v) ao ao 11 I O co 500 600 Detail Pressure Plot Time (sec) Tool Type XPT I . Mud Before Test Type Packer Volumetric Limited draw -down Conventional Probe 886.8 . � D rawdown Start Gauge CP_SAP L1 Buildup Start Formation Pressure 908.94 psia '? El End Buildup Last Read 894.55 psia .813.6 Drawdown Mobility 0.404 and /cp (0.26 cc) N / Mud After 2740.4 Mud Pressure Before 1039.59 psia Mud Pressure After 1039.21 psia a` Temperature Before /After 86.31 DEGF / 86.11 DEGF 667.2 Pretest Rate/Volume 0.28 c3 /s / 0.26 cc 594 50 545 640 735 830 925 Good Radial Time Func., Pres building, QC =10 Time (sec) 49 Flow Regime Identification Plot : File 62 Test 26 1810.90 ft (TVD) Schiumberger 1e +0e NICOLAI CREEK NO. 11 Radial Time Function Plot 1 — O Spherical Derivative - - - - - -- - - , 2000 - ' 1 ❑ Radial Derivative I I I 11 .4/111111 1e +04_ - _4_ �sM z, M ■■ ''./z‘ _ 1 •■■■ # oas , 0 1 e +0z, • CO cn 1 L _.. _ u) cn .•` CL130C il H % D cn cn le +02 K 1_1 J ■IENN■ =ME■ _..I, ■„1' 1e +01 1e +00 10+01 1e +02 Delta -Time (sec) Slope on Spherical 0.536 Slope on Radial 0.047 500 0.6 0.4 0 Radial Time Last Buildup Pressure : 894.55 psia Extrapolated Pressure : 908.94 psia Horiz. Mobility Thickness : 0.008 md.ft/Cp Radial Slope : - 3192.79 50 MN IIIN MI • MINI 11.11 EN IIIIIII 11111 MI MI • IIIIIM MI 111.1 IIIII MI IIIII • OM • RN ME • • = MI MI IMI MI MI MO MI 111. IIM Pressure Vs Time Plot : File 63 Test 28 1765.03 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 27 Test 28 1 o v o m co m m rn m n LL O U Q 0 _ 1 2_ • n �- a_ c a ~ a X 0. X ■ H 'U) ale' U I w a 2 X a ■ X o w X ce w > w a _ H a. w w a LL ~ < 1 o — i= a a 2 a G Q X a cl cn rt >- 2 I • O 0 O O O 1 __. __.._.._ ... ._.. O O O co N N II 300 400 500 600 700 Detail Pressure Plot Time (sec) Tool Type XPT 952 Mud Before T Type Volumetric Limited draw -down Packer Co V Drawdown Start 869.6 Gauge CP A Buildup Start Formation Pressure 899 nal Probe .06 psia m End Buildup Last Read 880.51 psia 0 -787.2 Drawdown Mobility 0.348 and /cp (0.29 cc) E E Mud After 2704.8 Mud Pressure Before 1013.46 psia E Mud Pressure After 1012.99 psia a` Temperature Before /After 85.34 DEGF / 85.16 DEGF 622.4 Pretest RateNolume 0.33 c3 /s / 0.29 cc 54 400 470 540 610 680 750 Good Radial Time Func., Pres building, QC =10 Time (sec) 51 Flow Regime Identification Plot : File 63 Test 28 1765.03 ft (TVD) Schlumherger 1e +05; NICOLAI CREEK NO. 11 Radial Time Function Plot ❑ Radial Spherical -. —___ Derivative ._ .. ■•∎ - • 2000 ative =MENEM�1■1■ MIN=M■■n ___ ■■II_=MME■ __ ■■■. I ■1 ■1 � I — ■ I Imo ■■■ _11 11E1111 ,e +r. I 111 !ii!!II!I i=iiii �- ! . �....- ..iEi■■. ■ 4 as I Ell �� -0 ' L!."- — 11300 L CD ' O .ti 1 * 7 • <>• N cn 10+02, I . ♦ ■ i II wilm■IMIIIIIIIIIM , =NM A.m. MEMO MEM ANIuI •■I , En 111 ' , III 1e +01 1e+00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.529 Slope on Radial 0.041 0 0 0 0 0 .11 500 0.6 0.4 0 Radial Time Last Buildup Pressure : 880.51 psia Extrapolated Pressure : 899.06 psia Horiz. Mobility Thickness : 0.006 md.ft/Cp Radial Slope : - 4582.05 52 MI M NM IMMI IIM 11111 NEI MB MI IMI OM aie MN MI = I MI MN MI MI • MB • NM NM MI • NM MI S MII • • MN NM 111. • OIM Pressure Vs Time Plot : File 64 Test 29 1734.98 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 O 0 0 0 o 0 C/5 0 0 0 T. Hil ___ ■ TO aI ci LL o v is U a o 1 a a ✓ - a v a a ¢ N II a ni a x a X H i w w W a f 2 X a a in X o ▪ o X 0 W > a a a 0 W CC ~ < i t W a U a ~ ra a X a o w cc o 1 2 “n o I O o o O o m l o o 1 A x 100 200 300 Time (sec) Tool Type XPT • Mud Before Test Type Unrecognizable Packer Conventional Probe V Drawdown Start Gauge CP 0 Buildup Start Formation Pressure psia End Buildup Last Read 929.67 psia 1. • Mud After Mud Pressure Before 996.12 psia Mud Pressure After 996.11 psia Temperature Before /After 84.74 DEGF / 84.63 DEGF Pretest RateNolume 0.28 c3 /s / 0.41 cc Unrecognizable 53 Pressure Vs Time Plot : File 65 Test 31 1736.53 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 o at o Test 30 l Test 31 o 0 0 0 a v 0 0 v S. P, o 0_I $. � g a 0 - I- I - = °-' X a X t r- a) U W 2 • a a x a • X o Ow x W > w a x 1- N m a d to w 0 o w w1 w w 1- a U a. a 2 Z a Q co , a. x N O x T O • 0 ✓ o 0 w v 0 0 o 0 u l N. N- o o w c v d J ,. -, 400 500 600 700 800 900 1000 1100 962 Detail Pressure Plot Time (sec) Tool Type XPT II Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe 872 in Gauge Drawdown Start Gau 9 e CP m 0 Buildup Start Formation Pressure 876.66 psia x782 • End Buildup Last Read Drawdown Mobility 876.66 psia • Mud After 0.122 and /cp (0.27 cc) 7 2692 Mud Pressure Before 996.78 psia Mud Pressure After 997.88 psia 0.. Temperature Before /After 84.16 DEGF / 84.2 DEGF 602 Pretest Rate/Volume 0.22 c3 /s / 0.27 cc 512' 525 625 725 825 925 1025 Building No time func., QC =7 Time (sec) 54 MS alle 011. IlM IIIM MI NM • MI NM IIIIIIII • 1111111 IIIIIII II MI MI 11.1 • OM INN NS NM MI 111111 11110 111110 111. MN MB NMI IMO NIN enhhimhannan Flow Regime Identification Plot : File 65 Test 31 1736.53 ft (TVD) 11/401111111sium woo 1e +0� NICOLAI CREEK NO. 11 _ 0 Spherical Derivative __ - - ■ ■■ — - - - -- - — 0 Radial Derivative M■ ■■ =MEM NNE • 1e +04 1■ ti p 1 e+0.: IFO ■ . Ir, ■ 1 .� 1e+02 0 II <41 Oo 1e +01 1e +00 1e +01 1e +02 Delta -Time (sec) 55 Pressure Vs Time Plot : File 66 Test 33 1673.00 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 9 Test 32 1 i Test 33 o r, m N Oi ai W m n LL 0 M U w = m > n 9 dI n .� a (-) a o_ a F a X d i X = F CD 0 W ~a 2 w a a x � � W x O W X D: W F N 2 a cn a W FO Q: 0 S a d Q Q X Q N N 12 0 } S I LO 0 O 0 A 0 v r r 0 o o 0 0 0 0 O o m 6 o o / \ 200 210 220 230 Detail Pressure Plot Time (sec) Tool Type XPT rn Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe 698.85 r ✓ y v Drawdown Start Gauge CP_SAP iti I X Buildup Start Formation Pressure 698.85 psia .N 1 I I 11 End Buildup Last Read 698.85 psia X98.65 Drawdown Mobility 12.497 and /cp (0.16 cc) d • Mud After = 2698.45 Mud Pressure Before 962.07 psia 2 Mud Pressure After 961.63 psia a Temperature Before /After 83.95 DEGF / 83.82 DEGF 698.25 Pretest RateNolume 0.17 c3 /s / 0.16 cc 698.05 175 215 255 295 335 375 Build Up, then down, QC =7 Time (sec) 56 MI MI MIII MIN IMIN MI MI MI OM MI MI l• MI 111. ONII .111 • MIN aall MN U 111111 NM • OIN 1.111 • OM Flow Regime Identification Plot : File 66 Test 33 1673.00 ft (TVD) Schlumberger 1e104 NICOLAI CREEK NO. 11 _ 0 Spherical Derivative _ 0 Radial Derivative - I O I.. 1e +02 8 • C 4 ❑ 0 1e +0e 0 - 0 u - v 00 0 • •, • 1 e +01 0 11 .i 1111. 0 1e +OG 1e +00 1e +01 1e +02 Delta -Time (sec) 57 Pressure Vs Time Plot : File 67 Test 35 1659.96 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 9 1 Test 34 I Test 35 ,o o 0 CO o 0 N N a a LL O _ U W S 9 5 !? dl a r — o a O a a a a = a' x a_ — X - w 0 w H ' x CC a w x O w X y W > w d = ai ai w a a W CC I- a w I- O CO CC a O o! p a F 2 a a a X a V N O 0! 0 I u) o hI N ('� Q O O N O O -, 1 I 1 1 1 00 200 300 400 500 600 700 800 Detail Pressure Plot Time (sec) Tool Type XPT 11 Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe CP SAP 702.67 pti 1 V Drawdown Start Gauge _ .10' �� " } I A I f�' (I, Buildup Staprt Formation Pressure 702.67 psia 702.47 'I `Y "J' " � ' End Buildu Last Read 702.67 psia I Drawdown Mobility 15.751 and /cp (0.55 cc) • Mud After D 702.27 ' Mud Pressure Before 954.23 psia Mud Pressure After 954.21 psia a_ Temperature Before /After 83.35 DEGF / 83.31 DEGF 702.07 Pretest Rate/Volume 0.37 c3 /s / 0.55 cc 701.87 300 340 380 420 460 500 Stabilized press, no Spher. or Radial Time func. Time (sec) 58 • NM MI MI • MI • MN • I= • MN M N MN UM • UM • In I • I MI In UM IMI MI MN IMI NM NM NM IIIIIII • NM • MN Flow Regime Identification Plot : File 67 Test 35 1659.96 ft (TVD) Schlumberger 1e +oa NICOLAI CREEK NO. 11 i l l I 1 1 _ 1 1 I II II — 0 Spherical Derivative — ❑ Radial Derivative 0 0 D p O 0 ❑ 4 I`∎ 1e +0'e ❑ 0 EL) 4Y " 1 0 ❑ 0 4> try D �` 1! �� 1e +01 ❑ � F.. �, *0 �� ■ �. •:✓ % K 7 - I i 1 . t CI,' . . X11 Is 1. - • 1 44. t �� „ L F II �i4 ` C, r . • II III • 1 e +00 1e+00 1e +01 1 e+02 Delta -Time (sec) 59 Pressure Vs Time Plot : File 69 Test 37 1452.98 ft (TVD) Schlumber er NICOLAI CREEK NO. 11 9 i Test 36 Test 37 o 0 0 o o o CD 0 0 � N g St LL ❑ M > - 2- 0 d a d v Q O d fn (0 H 0 _ X H CO O W a w I- X EL 0_ ❑ a w x O w X cY w > w a x CO m w a Cr_ w T 1- a w H O uj co K a O — F ± H I Q a H Q X Q EL N y 0 rY 0 2 r 1 e - o ■ 0 ul v O O O N O O O O _co O O 100 200 300 Time (sec) Tool Type XPT • Mud Before Test Type Dry Test V Drawdown Start Packer Conventional Probe Gauge CP_SAP A Buildup Start Formation Pressure psia El End Buildup Last Read 98.97 psia • Mud After Mud Pressure Before 836.69 psia Mud Pressure After 837.56 psia Temperature Before /After 80.11 DEGF / 80.17 DEGF Pretest Rate/Volume 0.38 c3 /s / 1.02 cc Dry Test 60 • • I • • • I • • I • • l= = • • • • NEN IMIII MI •IIII • I= INIII • MI MO MI 11.11 11.11 I•111 11.111 NM IMO UM 111111 Flow Regime Identification Plot : File 69 Test 37 1452.98 ft (TVD) Schlumberger 1e +04- NICOLAI CREEK NO. 11 — O Spherical Derivative -- - - ;:miTs,,iii — 0 Radial Derivative 1e +OC _� 1e +0' U) > �e ' / r: ..., ,,, 2 CL 1 e +01 rte • � 1111= nom ..iii lip • O ■ ■ O. 1 a 1 e +0 w �.. m ��� _�rawAv IN ■wim■mo r r 1e - 1e +00 1e +01 Delta -Time (sec) 61 Pressure Vs Time Plot : File 70 Test 39 1430.00 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 38 Q Test 39 o ° q 1_- I I _.„, • co cn V I LL 0 U w m ^w n 0 a' n • U Q a = w x a jill x r <n 0 � w ,,,-. .,.._.,- .., ,, °..�- X w x O w a. y w I- L a i aj a a I " a X Q U O K 0 O 0 0 N I e ° 0 0 ° o o 0 o co 0 0 ' A A I I r 100 200 300 400 500 600 Detail Pressure Plot Time (sec) Tool Type XPT 1 IN Mud Before Test Type Volumetric Limited draw -down �� I V Drawdown Sta Packer Conventional Probe 679.27 Gauge CP_SAP , W' 0 Buildup Start Formation Pressure 681.52 psia :479.07 End Buildup Last Read 679.27 psia • 1 2 Mud After Drawdown Mobility 0.605 and /cp (0.35 cc) m 678.87 Mud Pressure Before 825.89 psia Q Mud Pressure After 825.62 psia o Temperature Before /After 80.48 DEGF / 80.62 DEGF 678.67 Pretest RateNolume 0.29 c3 /s / 0.35 cc 678.47 375 420 465 510 555 600 Good Spher.Time Func., QC =10 Time (sec) 62 NM MN MI MN • MI IIIIII MI = I• NM • I • MN MI MI MI MI NM I= • MI I MI IMII MI • MI UM MIII M = MI NM • MII Flow Regime Identification Plot : File 70 Test 39 1430.00 ft (TVD) Schlumberger 1e +04 NICOLAI CREEK NO. 11 Spherical Time Function Plot : — ---- - - 800 ❑ Radial Derivative MM _ - - _ � -" Spherical Derivat p ./ _.. _ _ j ,, I II MIIM. ■ ■uI1�t•J i r -- - CD 1e +0" 1► r a) A ..z,i .7:' I � 1e +0 ■ � . 11 .. Mi ■ 11 M X 00 u) Sr u) o 1e +01 d •.. 1e+00 1e+01 1 e +02 Slope on Spherical 0.023 1:.; Delta -Time (sec) Slope on Radial -0.455 Ci III ►i C..; lit U' all ti 0 TY ill■ 416411' IP O O O 377 1 0.600 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 679.27 psia Extrapolated Pressure : 681.52 psia Buildup Mobility : 0.07 and /cp Spherical Slope : - 5767.97 63 Pressure Vs Time Plot : File 73 Test 41 1414.01 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 40 Test 41 0 0 0 <d co m ao m r N- V / i Li' n ci LL 0 U w I m a o a n O a v a a — 1- w a x a x ▪ I 1- co U w a X Cr a w x o o x 0: w > w a a = w u w a W Ca a F < w I- 0 in rn a W I- o S a ▪ 2 a a a x CL CL a `n `n y O 0: ■ O I O 0 - 0 o N A c O co O o c, ::1 g i0,4 I M A ' 400 500 600 700 800 Detail Pressure Plot Time (sec) Tool Type XPT • Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe 708.8 Drawdown Start Gauge CP Buildup Start Formation Pressure 725.57 psia • End Buildup Last Read 708.8 psia 708.6 Drawdown Mobility 0.344 and /cp (0.43 cc) N Mud After m 708.4 Mud Pressure After ore 816.11 psia d Temperature Before /After 80.69 DEGF / 80.81 DEGF 708.2 Pretest Rate/Volume 0.36 c3 /s / 0.43 cc 708 475 560 645 730 815 900 OK Radial Time Func. QC =7 Time (sec) 64 MI aill Il= MI NM • • NM On NM 11110 NM NM IIIII OM I• NM IM 1111. • IIIIIII MI MI IMII MI MII EN 111111 111. NB I•111 1111. MN MN 11•11 Flow Regime Identification Plot : File 73 Test 41 1414.01 ft (TVD) Schlumberger 1e +0'-- _ NICOLAI CREEK NO. 11 Radial Time Function Plot �_ i 2000 = 0 Spherical Derivative 1 - 4 _ ❑ Radial Derivative 1 I. 1e +04 rP > • > v - Pr p 1 e +03 ` J — 2 V cn 2 + Imo -' _ a 0- a N 1000 �" ti, n D to U rn �` 1e +o4 O o 1e +01 '1t:. le +00 1e +01 1e +02 0 0 0 O • t + tli � ∎ t • ' D Time (sec) Slope on Spherical 0.539 ) O Slope on Radial 0.047 0 0.7 0 0 Radial Time Last Buildup Pressure : 708.8 psia Extrapolated Pressure : 725.57 psia Horiz. Mobility Thickness : 0.007 md.ft/Cp Radial Slope : - 4682.96 65 Pressure Vs Time Plot : File 74 Test 43 1392.00 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 9 Test 42 i Test 43 o ul a+ I o a m o 0 m a G.' ' } -_ w I 2 n > 0 2 a I A t- a c) a F 0. a. i u l a x a a x w t X H w d 2 w F a D • X a O w X _ � W > w a = I CI w a a F 0 w W b a O = 0 o ✓ a a < X Q N u' N O 0 o I o o o v o v o o AL 0 0 o o c c 460 470 480 490 500 510 Detail Pressure Plot Time (sec) Tool Type XPT tt 1.11'10 y � igi.,� � \i/ f hAt • Mud Before Test Type Volumetric Limited draw -down Y , �'�'` + 'YV� W�nI fff � `VI Packer Conventional Probe 670.62 D rawdown Start Gauge CP_SAP A Buildup Start Formation Pressure 737.88 psia X70.42 . End Buildup Last Read 670.62 psia • Mud After Drawdown Mobility 3.447 and /cp (0.22 cc) m 670.22 Mud Pressure Before 803.8 psia Mud Pressure After 804.48 psia a_ Temperature Before /After 80.83 DEGF / 80.86 DEGF 670.02 Pretest RateNolume 0.25 c3 /s / 0.22 cc 669.82 450 500 550 600 650 700 Good Radial Time. Func. but build -down spike, QC =7 Time (sec) 66 = NM I• MI MB NE NM IIIIIII MI MO IIIIIII MN RN MN N — MN MI Flow Regime Identification Plot : File 74 Test 43 1392.00 ft (TVD) Schiumberger NICOLAI CREEK NO. 11 Radial Time Function Plot 1 e +04 r 1 I I 1 - 800 - - O Spherical Deri 0 Radial Derivative 4 N 1e +02 ,Vi c-.= `» • O li l: 0 - ♦ I'11_' • ..:.: D aD , 1e +0 0 f il Go D eL °' 600— Pi D le +01 a_ O 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.461 0 Slope on Radial 0.030 0 ) 400 0.6 0.4 0 Radial Time Last Buildup Pressure : 670.62 psia Extrapolated Pressure : 737.88 psia Horiz. Mobility Thickness : 0.028 md.ft/Cp Radial Slope : - 783.74 67 Pressure Vs Time Plot : File 76 Test 45 923.03 ft (TVD) Schlumberger NICOLAI CREEK NO. 11 Test 44 I I Test 45 o n n o ‘7, rn rn v a ii V - M LL 0 o o >- — J a 0 a n r-- F a 0 d a H 2 dl X d X I ~ N 0 w a 2 w 2 X Cr a F w X o W X 1- w > a a = (0 LU a a H 0 I- CO IX Lu W I- R' (.3 S re 0 0 a a 0 X Q N N n ce 0 >- 2 0 / o° _ _ a ° 0 0 o 0 P. _ l• C'' 200 300 Detail Pressure Plot Time (sec) Tool Type XPT 452.44 • Mud Before Test Type Volumetric Limited draw -down Packer Conventional Probe V Drawdown Start 452.24 + � 4 A f I i t �1° 1� B uildup Start t Gauge CP_SAP *1 +YV Formation Pressure 452.2 psia / E nd Buildup Last Read 452.24 psia 8452.04 ' Drawdown Mobility 25.027 and /cp (1.41 cc) a • Mud After 451.84 - P4 Mud Pressure Before 538.46 psia Mud Pressure After 539.12 psia a Temperature Before /After 79.77 DEGF / 79.52 DEGF 451.64 Pretest RateNolume 0.47 c3 /s / 1.41 cc 451.44 200 235 270 305 340 375 Good Spher.Time Func., building Press QC =10 Time (sec) 68 — MI an • MB MI • OM MI MI MI MI IIIIII MI MB IIIMI MO IIIIIIIII -- MN MI — — MI — MN — • MI MN — s NM — OM MI Flow Regime Identification Plot : File 76 Test 45 923.03 ft (TVD) Schlumberger 1e +0 I CREEK NO. 11 Spherical Time Function Plot : 1 600 _ - -- 0 Spherical Derivative N I t- LA I – — 0 Radial Derivative i 1 _ AI. 1e+0" i :" + - L z , -I 11r -- co d 1e +01 tt J _ : .• —MEND Mr — IIIII I. X00 .111 N 2 1e +OG a_ 1e +00 1e +01 1e +02 Delta-Time (sec) Slope on Spherical -0.046 ( ) Slope on Radial -0.494 r, I ,4 I I • 0 388 1.3 0.700 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 452.24 psia Extrapolated Pressure : 452.2 psia Buildup Mobility : 1.83 and /cp Spherical Slope : -72.04 69 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
