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211-040
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. p2 I L - 0 4-0 Well History File Identifier Organizing(done) ❑ Two-sided 1111111 III III ❑ Rescan Needed II 1111 1111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ M ps: reyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner olvp LOGS ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: dell. Date: • _ j /s/ m P Project Proofing111111111111 III BY: AM Date: ( Ay. I /s/ a/ , Scanning Preparation 1 x 30 = 3 0 + I (i. = TOTAL PAGES L Li (Count does not include cover sheet) vYi BY: Date: ai' ' Production Scanning 1111'111111111111 Stage I Page Count from Scanned File: 14-5 (Count does include cov sheet) Page Count Matches Number in ScanningPreparation: YES NO p BY: (aria) Date: (ofi%L,z.fI%L /s/ rnf) 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. HEIN 1111 ReScanned II 1111111111 VIII BY: Maria Date: /s/ Comments about this file: Quality Checked II IIIIIIIIIIIIII o I c 9 CoI 4 co ° -ti. Z 0 o = N r) U (0 o !311 tA c rl m °) E C) �I� kr) as as E o aa) o Z , U U 7 c 0 1 II co a) I > V o O U I0 Z N , H d Q ore re I J S I I 2 U I E c O w 2 a) Lu F_ Ni cc co x OU £ o C/ U a. Co O. 6' O 4.iu _ N y °' .. Z Z U 1° 0. in E } > Ct. Z z u) Z W Ce W r• , W 0 O � > a) V COCe N w z ` c a) cco pig 7 O Q + R' Z o H c O. Oc ° o d 0E ▪ M co ZI J � y ▪ C N y ; a, O a 1 o U M Eo E ' J J to CO U 0 Q j I O. o I �~C m N C 2 CO a CO111'^ f- a H m V) cc a Q o 'II I o E >-(431Q E Z . I t4., Q o ond U o E J Z z I 2 m a) E Co C d. z r w E Z O1 >. 0 ° y 0 C P Z Z Z I d CO I J O Q o < z -c c WOZ a Y > ; N cc 1 0 5 w a) O • m Oam° E aE yE LLc, I >wLL € Co °) z JQI 0 O 0 0 H a)N 0 O W I LL d Og d 0 C o N Q ' z W o ~ C >.� I £ a U ur .5 y '7 ~ o a)� n 0 ¢a U 0 0 STAITIE DT ., [1.[,\ SEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Natasha Sachivichik Senior Drilling Engineer Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, North Tarn 1A Brooks Range Petroleum Corporation Permit No: 211-040 Surface Location: 2388' FSL, 1780' FEL, SEC. 02, T1ON, R7E, UM Bottomhole Location: 1369' FSL, 4961' FEL, SEC. 01, T1ON, R7E, UM Dear Ms. Sachivichik: We are in receipt of your request to withdra th- above referenced permit. Based upon your request we have withdrawn - . ncelled the permit. 4 !rma. i m •: ioner DATED this / day of April, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 12, 2011 8:26 AM To: 'Natasha Sachivichik' Subject: RE: Withdrawal request for the North Tarn-1A PTD 211-040 Natasha, Will withdraw 211-040 as requested. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Natasha Sachivichik [mailto:natasha.sachivichik@solstenxp.com] Sent: Friday, April 08, 2011 2:51 PM To: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Cc: Darrah Bo; Armfield Bart; Bill Penrose; Jim Winegarner Subject: Withdrawal request for the North Tarn-1A PTD 211-040 Steve, Brooks Range Petroleum requests to withdraw the North Tarn-1A permit to drill, PTD 211-040, due to change of plans and submittal of a new sidetrack application for Permit to drill. Thanks, Natasha Sachivichik Senior Drilling Engineer 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com 4/12/2011 Davies, Stephen F (DOA) From: Natasha Sachivichik [natasha.sachivichik@solstenxp.com] Sent: Friday, April 08, 2011 2:51 PM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Cc: Darrah Bo; Armfield Bart; Bill Penrose; Jim Winegarner Subject: Withdrawal request for the North Tarn-1A PTD 211-040 Steve, Brooks Range Petroleum requests to withdraw the North Tarn-1A permit to drill, PTD 211-040, due to change of plans and submittal of a new sidetrack application for Permit to drill. Thanks, Natasha Sachivichik Senior Drilling Engineer S ;`'P 310 K Street,Suite 700 Anchorage,AK 99501 MAIN (907)264-6100 DIRECT (907)264-6116 CELL (907)575-7156 natasha.sachivichik@solstenxp.com 1 petroleuni FREE FULL T7 c �v SUM' Home 'd rri m Subscrrptlons AubHcattonsMrlis' http://www.petroleumnews.com/pnads/913686640.shtml 41k-- 0 0 BRPC spuds North Tarn a N. \ - OLA Joint venture begins work on the only North Slope exploration well for 2010-11 Eric Lidji For Petroleum News Brooks Range Petroleum Corp. spud its North Tarn No. 1 exploration well in the central North Slope of Alaska on March 13,the local independent said. North Tarn No. 1 is on state land east of the Miluveach River, about two miles west of the Kuparuk River unit. BRPC spud the well using Nabors rig 9ES and accessed the well site using a winter ice road and pad system built by Peak Oilfield Services. BRPC plans to drill the well to a total measured depth of 6,440 feet to target both the Brookian formation and the deeper Kuparuk formation. The Brookian is the same formation producing at Tarn, the Kuparuk River unit satellite just to the south, while the Kuparuk is the main formation producing at the prolific Kuparuk River unit to the east. BRPC estimates that the Brookian reservoir could contain some 35 million barrels of oil and that the Kuparuk reservoir could contain an additional 6 million barrels of oil. BRPC previously told Petroleum News that it believes the smaller Kuparuk formation presents a better bet for initial development because of the complex geology of the Brookian. BRPC hopes to complete operations at North Tarn No. 1 by mid-April,but also said it could also end up drilling a sidetrack to the well this winter, depending on results. "The BRPC Group is optimistically looking forward to see the results of the North Tarn No. 1 exploration well," said Jim Winegarner,vice president of land and external affairs for BRPC. "The North Tarn No. 1 exploration well is the only exploration well being drilled on the North Slope this season; therefore, the BRPC Group holds the title as Alaska's exploration company. We'd rather share that title with many more companies." While ConocoPhillips plans to drill a gas hydrates exploration well in Prudhoe Bay this year,North Tarn is the only traditional oil exploration well permitted this winter. BRPC is operating the well on behalf of its parent company, the Kansas-based Alaska Venture Capital Group LLC, as well as three joint venture companies: Brooks Range Development Corp., Ramshorn Investments Inc. and TG World Energy Inc. The joint venture acquired the North Tarn acreage in January 2010, farming-in six Eni Petroleum leases. Earlier this year, it applied to form the 56,460-acre Southern Miluveach unit over the area. That application is still pending with the Division of Oil and Gas. Seven wells in five seasons North Tarn No. 1 continues the joint venture's march toward being the most active explorer in Alaska over the past five years. Following half a decade of stops and starts after arriving in the state in 1999, AVCG formed an operating arm, gathered acreage, partners and data, and began drilling exploration wells across the North Slope. The joint venture drilled two wells in 2007—the North Shore No. 1 well that encountered 70 feet of oil charged Ivishak sandstone and the Sak River No. 1 dry hole. In 2008, the joint venture re-entered North Shore No. 1 to test the Ivishak and the Sag River formation, and drilled the Tofkat No. 1 well on acreage along the Colville River, taking 10 oil samples for four sandstone reservoirs and finding six net feet of pay. In 2009, a lawsuit among partners kept the joint venture from drilling, but the partners resolved it in time to return to the North Slope in 2010 with two wells: Sak River No. 1- A, a sidetrack to the 2007 well, and the North Shore No. 3 well in the Gwydyr Bay area. In addition to work at its Gwydyr Bay, Tofkat and North Tarn acreage, the joint venture wants to shoot seismic at its Slugger prospect, located south of the Point Thomson unit. Partner TG World Energy recently announced that it successfully sold its outstanding stock to the Canadian mining company TVI Pacific Inc. The deal allows TG World to raise capital and TVI to expand its resource development operations in the Philippines. TVI and TG World share a senior executive. aIndlIF R\ SE SEAN PARNELL,GOVERNOR �1 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Bart Armfield VP-Operations Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, North Tarn lA Brooks Range Petroleum Corporation Permit No: 211-040 Surface Location: 2388' FSL, 1780' FEL, SEC. 02, T1ON, R7E, UM Bottomhole Location: 1369' FSL, 4961' FEL, SEC. 01, T1ON, R7E, UM Dear Mr. Armfield: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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, . a •.mmission order, or the terms and conditions of this permit may result in the -vocatiIn or suspension of the permit. . or o • iss', er DATED this /77—day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED A KA OIL AND GAS CONSERVATION COM >IONAR0 PERMIT TO DRILL 20 AAC 25.005 {�,y -r .�f_ la.Type of Work: lb.Proposed Well Class: Development-Oil L] Service- Winj ❑ Single Zone ',r j tlt'� P�trAi�3 1011 Drill Q • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone Co Ibec j as Hydrates ❑ Re-entry ❑ Exploratory ❑✓ • Service- WAG ❑ Service-Disp ❑ .,.10 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well 11.Well Name and Number: SIDeig.) Brooks Range Petroleum Corporation Bond No. LPM 8421 4,11 North Tarn 1A • 3.Address: 6.Proposed Depth:7, cin,.. 3.(S(( pr,- 12.Field/Pool(s): 510 L Street,Suite 601,Anchorage,AK 99501 MD: j TVD: 6,396/45 ,/c(( 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Exploratory Surface: 2388 FSL 1780 FEL S2 T1ON R7E UM • ADL390680 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1777 FSL 192 FEL 2 T1ON R7EUM LAS27505 .Mach-30-2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1369 FSL 4961 FEL 1 T1ON R7EUM • 2,560.00 > 3 / /;'(‘../I 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 97 • feet 15.Distance to Nearest Well Open Surface: x-465198 • y- 5940773 • Zone-4 GL Elevation above MSL: 67 • feet to Same Pool: N/A 16.Deviated wells: Kickoff depth: 3temfee ,9.1 1,Maximum Anticipated Pressures in psig(see 20 AAC 25.035) . 3✓'•« Maximum Hole Angle: 10 degree• bownhole: 3096 psi . Surface- 235_pSi ' 18.Casing Program: Specifications Top - Setting Depth - Botto • Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 0.495"WT N/A Welded 80' 0' 0' 107 140 cf arctic grade cement 4 12.25" 9-5/8" 40# L-80 BTC 2660 0' 2660 2631 Cmtd to suit w/502 bbls L tpL4,J raez N r i 7f`" 3•/.-# '. 19. PRESENT WELL NDITION SUM ARY � • .e completed fo -edrill and Re-Entry Operations) Total Depth MD(ft): Total De th (ft): Plug: iv• :•): ffect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing ( igth - ze Cement Volume MD TVD Conductor/Structural ``` 1 Surface i// Intermediate 1M��t` Production iji, ,j(k),i, ,1 Liner ✓11i Perforation Depth MD(ft): 1 rt. - .n Depth TVD(ft): J 20. Attachments: Property Plat ✓ BIp S etch ✓ g Program ✓ Time v.Depth Plot ✓ Shallow Hazard Anal sis ,_,J i iter ketch❑ •bed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Represent ti : Date 22. I hereby certify that the foregoing is true an c rr ct. Contact N.Sachivichik 575-7156 Printed NaBart A rmfield Title VP-Operations Signature f it► V) Phone 907-339-9965 Date 3/41 f ' Commission Use Only Permit to Drill • lAP Number: lvc Permit A r val ` See cover letter for other Number: ��V�V 50-/05'zn ,•3 6/wDate: \`i 1,` requirements. Conditions of approval: If box'- checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: u Other: X 35C0. r .40 1° ."--e--.Sq— - Samples req'd: Yes❑ NoQ' Mud log req'd: Yes R'No❑ 111-ZS /�-6 D fr ' »n wLL . (e� - 6114...„) H2S measures: Yes Eli No❑ Directional svy req'd: YPs ✓�No❑ -7 C• p sf 6:7 L • I - c�.�� j / "'"r� j�51 /?t r4 aper S � (/ �� APPROVED BY THE COMMISSION •✓ DATE:3•••/�.•/l �I COMMISSIONER 1 ORIGINA S-( Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate / #)/\/\ Brooks Range Petroleum Corporation 510 L Street,Suite 601 *Anchorage,AK 99501 *Phone(907)339-9965* Fax(907)339-9961 March 14, 2011 Mr. Dan Seamount, Chair RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7t1i Ave., Suite 100 Anchorage, Alaska 99501 MAR 14 2.011 RE: Application for Permit to Drill: North Tarn#1A Mash &ens Cons,,Commission Anchorage Dear Mr. Seamount, Brooks Range Petroleum hereby applies for a Permit to Drill a sidetrack oil exploration well North Tarn#1A (NT-1A) from an ice pad to the east of the 2L pad of Kuparuk field on the North Slope. Brooks Range plans to use Nabors Rig#9-ES to drill this sidetrack. NT-1A drilling will be conditioned on oil discovery in the NT-1 which is currently being drilled. The NT-1 (PTD 211-001) application for a permit to drill was submitted and approved earlier. The NT-1 will be evaluated and later plugged back to -3000' MD. Brooks Range plans to drill the North Tarn-1A as an 8-1/2" hole from 3,000' MD to the Kuparuk sandstone to 7,320'MD/6,453'TVD. The objectives of this operation are to locate oil reservoirs in the Brookian and Kuparuk formations and to evaluate the reservoir . and properties. During drilling of NT-1A the Brookian formations will be cored. After the drilling program is completed, the North Tarn-1A hole will be plugged back with cement extending at least 100' into the 9-5/8" casing. A bridge plug will be set at 250' with cement on top of the bridge plug inside the 9-5/8" casing. The wellhead will be left in place to allow drilling future sidetrack wells from this location. 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) Proposed general drilling program 4) Drilling Time versus Depth Plot 5) Current Wellbore Diagram 6) Proposed Wellbore Diagram 7) Pressure Calculations, Drilling Area Risks and Waste Disposal 8) Diagrams and Descriptions of the BOP Equipment to be Used 9) Directional Drilling Program 10) Drilling Fluid Program 11) Cementing Program for plug back operations L--� A. ;4- is Fc,41, 41 1 Nor IA 12) Brooks Range 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. 13) The following are Brooks Range's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Natasha Sachivichik, Drilling Engineer (20 AAC 25.070) (907) 264-6116 2) Geologic Data and Logs Doug Hastings, VP - Exploration (20 AAC 25.071) (907) 865-5802 If you have any questions or require additional information, please contact me at (907) 865-5840 or Natasha Sachivichik at(907) 264-6116. Sincerely, BR OKS RAN E PETROLEUM CORPORATION OFATIP ‘4 - � r � Bart Armfield Vice President - Operations enclosures cc: Natasha Sachivichik - SolstenXP 2 North Tarn #1 A General Drilling Program ,_ 356°/°' 1. Notify AOGCC 24 hours prior to testing BOPE. Test BOPE to 250 psi low and47eeepsi high (See Permit to Drill for reference). 2. MU 8-1/2" BHA and test. Oil based mud will be used to drill the sidetrack. 3. MU 8.5" BHA#1.Circulate and establish baseline parameters. LWD will include the GR, RES, ' DEN, NEU, NMR. 4. Kick off of the cement plug set at 3000' and drill ahead an 81/2 " hole with mud motor and LWD-PWD system to top of the North Tarn at 4800' TVD. The core point will be selected by the wellsite geologist. r 'A"1-4'- 5. ,145. POOH and Prepare to core Brookian (North Tarn zone). • 6. Core through the Brookian sands. POOH. 7. Ream through the cored interval and drill ahead with drilling BHA and LWD. The LWD logging suite will include GR, RES, DEN, NEU, NMR. • II;5 8. Continue drilling through Kuparuk. Allow ample rat hole to run all LWD tools through the Pra Kuparuk Sandstones. Back-ream and MAD pass through the Kuparuk sands. POOH BHA. 9. After the drilling operations are complete, POOH. At this point a decision will be made whether to run additional open-hole logs. Open-hole wireline logs will include dipole sonic. • j10. Plug back the NT-1A hole to ^'100 ft inside the 9 5/8" casing. ---Y. Pei' P(k J'''.'') f 6°`f 14` `".d 11. If the reservoirs were not encountered,the well will be P&A-ed and a decision ill be made Aocicc.. about the next steps in the program. iccn1• r �( n L . �0+;"�'') ce�� ASS. aye w • . ;n �G. 6.�?��er` G ul , J • , I) , of erdleh.r, k cc)i kin it L f.t' U • M • • 00 7 0, L 'L Q O O U Y 0 M C 00 f0 C :2 ,... O O U OL N Ca U) F- C O Y (J CD ca O >. 0 ti4 W G = a a CCU) C t E a`) = • a- 2 0f0 Oa 03• 0 W N r as * a u, C L H CU Z N 7 N > cc W O o L/) • • • O ■ i O O O O O O O O O O O O O O O O r N (6 lf) (D I: CO (;eat) Ladea paanseaw North Tarn # 1 and #1A Proposed Wellbore Diagram 16" conductor set @ 80' ' p MD/TVD I 4 II if ee I r^p 2500' MD, 9-5/8",40#, 1-80, BTC casing • Sidetrack NT-1A below the 9-5/8" shoe Maximum Hole angle 11 deg at 4800' North Tarn Hole angle at TD 9 deg core intervals // PA-GT " 6rham) 81/2" Open Hole 8%2" Open Hole l / p/(4.‘ -eti ( tc,.�.r a,.�.,�-) Kupatuk ; co / iatervaf s NT-1A 7,495 ' MD/6,403' NT-1 TD 6,484' MD/ 6,398'TVD TVD ns 12/27/10 Geo-Mechanical Plot Geomechanical Plot North Tarn #1 8 9 10 11 12 13 14 15 16 17 0 - - —1 80'ND 16" conductor 1000 - i B Per afrost - .95' 2000 - --- -10- 261.' ,, -LOT,- '2fl'TVD- 2660' ND 9 5/8" LOT, 2819 3000 Projecte. Pore Frac 1 LOT 4000i,,-. 1 „MW NT . P,- AUTh- ten j/ 5000 --- To N Tarn 5 14' 6�I, �� �t� C30 Ss - 5715' <5 9C / K + J /y) 6000 .�-_ Top . _6• • - '- -- -11 • L•_ 00' 7o-76/"ts i 4, r TopK.iubik -6 •l_c ? '�i—n — 7V r7-1› Pore Pr- • e 94 / -- pp` !:._' Top K p C-1 63.0' ` .S -- Z `/S 'mD -_ - ----- 7000 LCU -6361' (47 -rq i�1j /') t\yA\ Brooks Range Petroleum Corporation Brooks Range Petroleum Corporations Pressure Calculations,Drilling Area Risks and Waste Disposal Considerations North Tarn#1A Maximum Anticipated Surface Pressure: 12-1/4"Hole Section This hole section will be drilled with a diverter only, no BOPs. While MASP will equal the formation pore pressure at the surface casing shoe depth of 2,660'MD/2533' TVD less a gas gradient to the surface, it cannot be shut in, only diverted. Offsetting well information indicates that the pore pressure at 2,533' TVD will be a maximum of 9.0 ppg (or 0.468 psi/ft). Calculations for MASP (12-1/4"hole) =2,533' (0.468-0.10) =932p si 8-1/2"Hole Section The maximum anticipated pressure (MASP) for the 8-1/2"hole section will be the formation pore pressure (less a full gas column to the surface) at 6,483' MD/6398' TVD. . • Offsetting well information indicates that pore pressure at TVD will be a maximum of 9.0 ppg (or 0.468 psi/ft). Calculations: 8-1/2"hole section MASP (pore pressure) = (6,398 ft) (0.468-0.10) = 235�si • With MASP in the 8-1/2" open hole section is expected to be 2354 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risks: The closest wellbore to the North Tarn#1 is DS 2L-03, it is located approximately 2.0 - miles away and the directional simulation indicates there is no anticipated interference expected between wellbores. /V \ Brooks Range Petroleum Corporation Drilling Area Risks: 1. There is a possibility of encountering gas hydrates while drilling the surface hole. If gas hydrates do occur in the North Tarn#1, the situation will be treated with extra care, slow down drilling, slightly increase mud weight and set surface casing and cement as soon as possible. 2. There is little risk of encountering H2S in the area as there are no indications that any of the offsetting wells encountered any. However, as a precaution, the rig and mud logging units will have functioning H2S detectors. 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Rolary Teble(97811 above MSL) Mag Dec: 20.928° FS 57605 9n Lon: W 1501652.183 EastIng. 465168.00}ICS Sub Fact:0.99990138 Plan. 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Z i/ ! | ..._ ) A § 2!) ^ W ƒ !\72, R v- 8 '\ 8 , ) )� us !1§ ))} § {\ ( \ I-RI FA }) k 2. § \ '` ■ \ :. % U 0 E:: 0 § a { ° . 2 « _ 2 �\ C J E } 113 2 ...} , k_ z ! a g «< N U»GWI.=ate S >» Brooks Range Petroleum Company North Tarn #1 Mg SWACO ./4111WINIVIShi. Brooks Range Petroleum NORTH TARN #1 / 1A Mud Program Name Signature Date Originator: Jim Dwyer December 31, 2010 Reviewed by: Hal Martens Customer Approval: Version: 2.0 Date: December 31, 2010 Confidential 1 Brooks Range Petroleum Company North Tarn #1 Production Interval 1A Drilling Fluid System VersaPro NT Key Products LVT-200, IMG 400, Lime, VERSACOAT HF, VERSAWET,VERSAMOD, VERSAHRP, S-200, Brine (10.8 ppg CaCl2), MI WATE (Barite) Solids Control Shakers, Mud cleaner, Centrifuge Lithologic instability near the wellbore. Potential Problems Lost Circulation Hole cleaning. Production Interval Drill-in Fluid Properties Properties Initial Value Density(ppg) 10.0 ppg by TD Funnel Viscosity(seconds) 35 -45 Yield Point(cP) 15 -28 Plastic Viscosity(lb/100 sf) 15 -25 Oil :Water 70 : 30 Electrical Stability(mlVolts) 650 -900 HTHP Fluid Loss (ml/30 min/200 psi/150°F) <4 Date: December 31,2010 Confidential 1 1 Brooks Range Petroleum Company North Tarn#1 Production Interval "IA" S.C.E. Operation Standards: Shakers- • Inspect decking rubbers, do as necessary. • Install XR Magnum screens (175-210 mesh). Ensure screens are properly tensioned, per M-I Swaco's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • Set counterweights to 90% (7.8 G's)for optimum performance. • As fluid shears, screen up as necessary to higher mesh screen sizes. 210 mesh is optimum to reduce sand sized particles. • Ensure jacking system on ALSII shakers enables the fluid to flow to the center of the screens, adjust and lock as necessary. De-Silter- • Ensure cuttings trough bypasses shakers, and goes into cuttings ditch. Failure to do so will allow small particles to enter right back into system through the flow line shakers (84-110 mesh screens). • Install 3/8"Apexes. • Ensure that"feet of head"gauge is available at the De-Silter, not the pump. • Ensure that De-Silter feed pump can achieve 95' of head. CRITICAL! • Monitor discard, change apexes as necessary to improve solids content in mud (it may be determined that 3/8" apexes can be installed if cuttings in the system happen to be finer than presumed) • Discard should be 2-3 ppg over feed weight. Centrifuge- • Production intervals generally call for a "high-speed" centrifuge, which is rotating at approximately 3200 rpm's. This allows the centrifuge to make the 3-6 micron cut, and eliminate a percentage of the "ultra fine" cuttings from the fluid. Through put must be decreased while running the centrifuge at 3200 rpm's, since there is a greater risk of "packing off" the centrifuge back drive and auger. Swaco would also suggest installation of amp meter on the back drive motor which will allow the operators to monitor the feed rates by knowing how much torque the back drive motor is receiving while trying to discharge the cuttings. • Refer to mud man for solids information to determine speed and feed rate of centrifuge. • Continual processing at low feed rates will yield better results than shutting centrifuge down and starting it up. Slow feed rate down to maintain an acceptable weight if needed. Date: December 31,2010 Confidential 12 Brooks Range Petroleum Company North Tarn #1 Production Sidetrack Interval Considerations ➢ Ensure that the fluid properties are maintained to provide the best possible hole cleaning. Maintain mud weights as per drilling program guide lines and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Monitor for any fluid losses and flow back closely. ➢ Control the ROP and flow rates as needed to avoid inducing a breakdown of any formations. Reduce pump rates immediately if packing off occurs. Pump high viscosity weighted sweeps and ream carefully to clean the hole before proceeding with further drilling ➢ Adjust rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Use good drilling and tripping practices. Break circulation slowly — Reduce pump speed 15 to 20% while reaming down. ➢ As an exploration well, pore pressure uncertainty also exists. Use all means possible to evaluate well conditions to determine if fluid properties are in line with the needs of the well. ➢ Monitor and record drilling parameters on each connection and before and after any lubricant additions. ➢ Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a second high viscosity/weighted sweep and observe bottoms up again. ➢ Establish good hole conditions for any logging and testing that may be performed. ➢ Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. Date: December 31,2010 Confidential 13 Brooks Range Petroleum Company North Tarn#1 Surface Interval Hydrate Issues Use the following guidelines to help minimize the effect that any hydrates which may have to the drilling operation. • Add 2 ppb Lecithin to the mud prior to drilling into the zone below the permafrost. CF DESCO II may be used to adjust rheology after the Lecithin additions are made. • Weigh the mud at both the possum belly and at the suction pit using pressurized and regular mud balances to determine the amount of gas that has become entrained in the mud. • Maintain the fluid at below 60°F if possible. • Minimize circulation time to reduce hydrate thawing. • Watch both drill rates and flow rates and make adjustments as needed to help diminish any problems that the surface equipment may have in handling the fluid and cuttings while circulating out any hydrates. • Weight up prior to drilling out of the permafrost. Watch the rate of depletion of the hydrates and increase the weight as needed to control the gas breakout from the hydrates. Barite Sag Concerns Barite Sag (a reduction in the MW out due to the dynamic and static settling of barite) is a potential drilling hazard while using weighted fluids. Although this well is designed for a mud weights below—11.5 ppg unexpected conditions may make additional weight ups or lubricant additions necessary. Both of these changes may contribute to a more likely chance of barite sag issues. Barite Sag is also aggravated by circulating at low rates for extended periods of time or while tripping with drill pipe or casing. As a consequence, if it becomes necessary to circulate at reduced rates, it is recommended that the pit watcher weigh and record MW out using a pressurized and un-pressurized balance every 15 minutes. Trips and casing running should also be closely monitored for indications of barite sag. Date: December 31,2010 Confidential 14 Brooks Range Petroleum Company North Tarn #1 Lost Circulation Guidelines for Water-base Mud Losing fluid while drilling Stop drilling and observe levels w Yes Losses on surface 1 ill ti Locate and stop losses V Yes Well flowing? Record shut in pressure.Kill the well Measure rate of loss ' 1 f w Seepage losses< 10 bbl/hr Partial losses 10-100 bbl/hr Total loss of returns l 1 1 Water-based Water-based Water-based mud mud mud 1 Pump 100 bbl pill of: Continual additions of Mix Pump 50 bbl pill of: CaCO3 60-20 ppb II at 4-8 sacks/hr Change CaCO3 60-20 ppb shaker screens to 84 mesh CaCO3 15-15 ppb if convenient. CaCO3 15-20 ppb CaCO3 500-15 ppb MI Seal-20 ppb MI Seal-20 ppb Mix 11 10 ppb Nut Plug-20 ppb Mix 11-10ppb • 1 Spot pill: No success Spot plug: Mica M 10 lb/bbl VersaPac or"Form-a"pill or No success —Mix II M. 15 Ib/bbl Reverse Gunk or Cement Mix II Coarse 10 lb/bbl Spot plug: G-Seal 20 lb/bbl "Form-a"pill or Calc.Carb(C) 10 lb/bbl Gunk or Nut Plug M 10 lb/bbl Cement Date: December 31,2010 Confidential 15 Brooks Range Petroleum Company North Tarn #1 Recommended Lost Circulation LCM guidelines for VERSAPRO NT MOBM The following lost circulation "Decision Tree" is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its' compatibility with base oil and ability to seal with minimal formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed)much easier. Losing fluid while drilling 1 Stop drilling and observe levels 1 Yes I— Losses on surface No Locate and stop losses Yes Well flowing? Record shut in Measure rate of loss pressure. Kill 1 1 1 Seepage losses< 10 bbl/hr Partial losses 10-100 bbl/hr Total loss of returns • Oil/synthetic Oil/synthetic Oil/synthetic mud mud mud � � l Spot pill: Spot pill: Squeeze pill: G-Seal 15 ppb H No success '-11). Mica M 7 ppb �""""'" FORM-A-SQUEEZE 80 ppb Calc.Carb.(M)10 ppb Calc Carb Med. 10 ppb in base oil weighted up to Calc.Carb(C) 7 ppb G-Seal 20 ppb desired density Calc.Carb(C) 7 ppb No success Ensure particle sizes of bridging materials can pass through the downhole tools and motors prior to mixing and spotting. Spot pill across thief zone, if losses stop, pull into casing and apply 50-100 psi squeeze pressure and watch for pressure bleed- off. If pressure holds for 15 minutes, resume drilling. If pressure does not hold, spot another pill as described above. Be sure to clear the motor with any Lost Circulation pill. Date: December 31,2010 Confidential 16 Brooks Range Petroleum Company North Tarn #1 Recommended LCM Pill for VersaPro System The following lost circulation pill is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its' ability to seal with minimized formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed) much easier. ➢ To existing VersaPro NT circulating fluid make a LCM pill with: • 15 ppb LoWate (fine calcium carbonate) • 15 ppb Safe-Carb Medium (medium calcium carbonate) • 15 ppb Safe-Carb Coarse (course calcium carbonate) Insure particle sizes of bridging materials can pass through the downhole tools and motors prior to mixing and spotting. 1. Spot pill across thief zone, if losses stop, pull into casing and apply 200-psi squeeze pressure and watch for pressure bleed-off. If pressure holds for 15 minutes, resume drilling. If pressure does not hold, spot another pill as described above. 2. If losses cannot be stopped with calcium carbonate only, mix up a LCM pill with 25 ppb MIX II Fine and 15 ppb MIX II Course cellulosic material and spot as above. If seepage losses occur after drilling is resumed, consideration should be given to adding 5 -8 ppb MIX II Fine cellulosic material to system while circulating. Date: December 31,2010 Confidential 17 Brooks Range Petroleum Company North Tarn#1 HSE Issues Handling of Drilling Fluid Products Health and Safety D Drilling crews should be instructed in the proper procedures for handling fluid products. D Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. D PPE must be in good working order and be utilized as recommended by the PPE charts. D Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. D Ensure all MSDS sheets are up to date and readily available for workers to access for information. Environmental D Ensure that all product stored outside is protected from the weather. D Do not store partial units (sacks)outside if possible. D When transferring fluids and/or cuttings from the rig to tanks, ensure all hoses are properly secured. Perform a transfer checklist as needed in order to avoid spills. Date: December 31,2010 Confidential 18 Brooks Range Petroleum Company North Tarn #1 PPE Chart HAZARDOUS MATERIALS IDENTIFICATION SYSTEM Product Function Health Flammability Reactivity PPE CAUSTIC SODA Alkalinity control 3 0 1 X PH-6 pH Adjuster 1 0 0 E DEFOAM X Defoamer 1 1 0 J CF DESCO II Dispersant 1 1 0 E SCREENKLEEN Surfactant 1 1 0 E GREEN CIDE 25G Biocide 3 0 0 J MI WATE (Barite) Weighting Agent *1 0 0 E MI GEL Viscosifier *1 1 0 E MIX II Lost Circulation Material *1 1 0 E DRISPAC PLUS SL Fluid Loss Reducer 1 1 0 E SAPP Dispersant 1 1 0 E MI GEL Viscosifier *1 1 0 E GELEX Bentonite Extender 1 1 0 E LVT 200 Mineral Oil 1 1 0 J VG SUPREME Viscosifier 2 1 0 J LIME Calcium Source 2 0 0 E VERSACOAT HF Emulsifier *2 3 0 J VERSAWET Drilling Fluid Additive 1 1 0 J CACL2 Weighting Agent 1 0 1 E VERSA-MOD Rheology Modifier 1 2 0 J VERSA HRP Viscosifier 2 1 0 J SAFECARB Bridging Agent *1 0 0 E (HMIS) HAZARD RATINGS 4- Severe hazard 3 -Serious hazard 2- Moderate hazard 1 - Slight hazard 0- Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A- Safety Glasses B- Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E- Safety Glasses, Gloves, Dust Respirator F- Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G -Safety Glasses, Gloves, Vapor Respirator H -Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K-Air Line Hood or Mask, Gloves, Full Suit, Boots X- Consult your supervisor for special handling directions. Date: December 31,2010 Confidential 19 Brooks Range Petroleum Company North Tarn #1 See Material Safety Data Sheets(MSDS)for more information M-I L.L.C,Occupational Health Department (Revision—April 10,2003) Houston,TX,Telephone: 281/561-1509 M-I L.L.C,Occupational Health Department (Rev.4 Aug-98) Houston,TX,Telephone: 281/561-1509 080598PRHS-1 rri 7 0 1, �(,---Th 1 q 0 \ ' Date: December 31,2010 Confidential 20 /N>V. N\ Brooks Range Petroleum Corporation Brooks Range Petroleum Corporation 510 L Street Suite 601 Anchorage, AK 99501 North Tarn North Slope Alaska T A) North Tarn 1 ( '�� Cement Plug Job Design Report For: Natasha Sachivichik Date: Monday, December 20, 2010 Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application,therefore,by the user of this report or any part thereof, is solely at the user's own risk. HALLIBURTON Brooks Range Petroleum Corporation ♦ /"�7 ,r Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 8-1/2" OH Plug Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 MD 6,602' TVD 6,453' Prey.Csg: 9-5/8"40#/ft BHST 105°F Previous Casing Depth: 2,660' BHCT 85°F Objective: Set a series of balanced plugs from TD to 5,014'across the oil bearing zone(KUP C and North Tarn Sands) in the 8-1/2"OH section. Slurry Recommendation: Balance plug calculations will be provided prior to the job. TO Plug 1:6,600'to 5,514'— to be Tagged �� ,646,c0:"0 r" " Spacer 20 bbl 11 ppg Dual Spacer f i, 14hecs• Slurry: 99 bbl—231 Sks. Premium Cement,3%Econolite,+.5%CFR-3,+0.5%Halad-344,and HR-5 as required Plug 2:5,514'to 5,014'—To be Tagged 4 w:-Lwe ss• Spacer 20 bbl 13 ppg Dual Spacer Slurry: 45.6 bbl—223 Sks. Premium Cement,+ 1%Calcium Chloride,+0.2%CFR-3,+0.5% Halad-344,and HR-5 as required Spacer Plug 1 Slurry Plug 2 Slurry Density(ppg) 11/13 12 15.8 Yield(cu ft/sk) 2.41 1.15 Water requirements(gal/sk) 14.3 5 Thickening Time Hr:min. 3:00—4:00 3:00-4:00 Volumes based on: Tail Slurry: Top of slurry—5,014'MD 1,586' calculated 8-1/2"OH volume+30%excess /_o r iv. to.% tel. HALLIBURTON 19 Brooks Range Petroleum Corporation Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 8-1/2" OH Plug - Kick Off Plug -7 r ' IA SST' Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 Prey. Csg: 9-5/8"40#/ft BHST 60°F Previous Casing Depth: 2,660' BHCT 55°F Objective: Set a 500'balanced plug from 3,500'to 3,000'in the OH section to provide a plug to sidetrack to the well. Slurry Recommendation: Balance plug calculations will be provided prior to the job. Spacer 20 bbl 11 ppg Dual Spacer Slurry: 45.6 bbl—259 Sks. Premium Cement,+.5%CFR-3,+0.5%Halad-344,and HR-5 as required Displacement: Mud 1313i'/6 t' p'? Spacer Tail Slurry D. SNS Density(ppg) 11 17 Yield(cu ft/sk) 0.99 Water requirements(gal/sk) 3.82 Thickening Time Hr:min. 3:00—4:00 Volumes based on: Tail Slurry: Top of slurry—3,000' MD 500' calculated 8-1/2"OH volume+30%excess HALLIBURTON 20 Brooks Range Petroleum Corporation /W\l4\ Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1A 8-1/2" OH Plug Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 MD 6,602' TVD 6,453' Prey.Csg: 9-5/8"40#/ft BHST 105°F Previous Casing Depth: 2,660' BHCT 85°F Objective: Set a series of balanced plugs from TD to 5,014'across the oil bearing zone(KUP C and North Tarn Sands) in the 8-1/2"OH section. Slurry Recommendation: Balance plug calculations will be provided prior to the job. Tv — -1,Ltoo . Toe K44.1,rtr e 739 5`kb Plug 1:6;690'to 5;514'—Not to be Tagged WiAiSpacer 20 bbl 11 ppg Dual Spacer Slurry: -499 bbl—231 Sks. Premium Cement,3%Econolite,+.5%CFR-3,+0.5%Halad-344,and loco (7 HR-5 as required Plug 2: '—To be Tagged -roP Ta r►, $9 8V 144) .f;rn Spacer 20 bbl 13 ppg Dual Spacer Slurry: —+ 45.6 bbl—223 Sks. Premium Cement,+ 1%Calcium Chloride,+0.2%CFR-3,+0.5% ca. P Halad-344,and HR-5 as required Spacer Plug 1 Slurry Plug 2 Slurry Density(ppg) 11/13 12 15.8 Yield(cu ft/sk) 2.41 1.15 Water requirements(gal/sk) 14.3 5 Thickening TimeHr:min. 3:00—4:00 3:00-4:00 e g Volumes based on: Tail Slurry: Top of slurry—5,014' MD 1,586'calculated 8-1/2"OH volume+30%excess {{,, �� 7c7"-"' 1 A t'1Las \I c r Al -7./6 •U HALLIBURTON 21 Brooks Range Petroleum Corporation ~\/\ Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 9-5/8" Surface Casing Shoe Plug Well Conditions Hole Size 8-1/2" Volume Excess 30% Mud Wt. 9.5 ppg Mud PV/yP 16/24 Prey. Csg: 9-5/8"40#/ft BHST 45°F Previous Casing Depth: 2,660' BHCT 55°F Objective:To effectively segregate the uncased and cased portion of the wellbore a EZSV bridge plug will be set 100' above the 9-5/8"casing shoe and cement downsqueezed through the plug.A 200' cement plug will be squeeze through the plug and a 50' cement plug will be placed on top of the bridge plug. Slurry Recommendation: Slurry: 20.5 bbl—47.8 Sks. Premium Cement,3%Econolite,+.5%CFR-3,+0.5%Halad-344, and HR-5 as required Displacement: Mud Slurry Density(ppg) 12 Yield(cu ft/sk) 2.41 Water requirements(gal/sk) 14.3 Thickening Time Hr:min. 3:00—4:00 Volumes based on: Tail Slurry: Top of slurry—2,510'MD 100' calculated 8-1/2"OH volume+30%excess+ 150'9-5/8"40# Casing volume HALLIBURTON 22 Brooks Range Petroleum Corporation irs>.,\Y\ Cementing Services North Tarn 1 Brooks Range Petroleum Corporation North Tarn 1 9-5/8" Surface Plug Well Conditions Hole Size 8-1/2" Volume Excess 10% Mud Wt. 9.5 ppg Mud PV/yP 16/24 Csg: 9-5/8"40#/ft BHST 45°F Casing Depth: 2,660' BHCT 55°F Objective: Set a 150'balanced plug from 155'below the surface 5'below grade. Slurry Recommendation: Balance plug calculations will be provided prior to the job. Slurry: 12.5 bbl—73 Sks.Type C Permafrost Cement. Displacement: Mud Tail Slurry S Density(ppg) 15.6 Yield(cu ft/sk) 0.96 Water requirements(gal/sk) 3.81 Thickening Time Hr:min. 3:00—4:00 Volumes based on: Tail Slurry: Top of slurry—5'MD 150' 9-5/8"40#Casing volume+ 10%excess IHAL.L.IBURTON 23 W \ �` CID 1 V O 1 1 • 0 2 I - Sit < 1 O L O N J ZV Q a m 0NQOJ a y ^-i D SOHO < I ii lN401 ti. u X CO dQ h. 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TRANSMITTAL/LETTER CHECKLIST WELL NAME 0,4A, PTD# 2— 1 VO Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: .6-,41,4:.r4�o y POOL: 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(f), 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 full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or 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. 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