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210-139
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. c 4 0 - 4 3 q Well History File Identifier Organizing(done) ❑ Two-sided I 1111 ❑ Rescan Needed 13111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: j ❑ Logs of various kinds: NOTES: ❑ Other:: • BY: AM Date: a 14.11 /s/ fj Project Proofing II BY: 411E. Date: /s/ viip Scanning Preparation x 30 = + = TOTAL PAGES c2 (Count does not include cover sheet) ni BY: Maria Date: a ![.1 /4 /s/ Production Scanning 1 111111 III 11111 Stage 1 Page Count from Scanned File: a3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: (/ YES NO BY: (Maria) Date: /L4. ' 4. /s/ P 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. I ReScanned 13111111 I BY: Maria Date: Is/ Comments about this file: Quality Checked II llIIIIIIIII 19/99/9n11 AA/.II uicrnr.,MI.(`nv.r Don.Ann O C O iis es 9 2 1 n as 1 0) m r z 0 N = o) U y a) — m 3 c IN > >I a) o ? E N T N E Z 0 V F. co c Q Ts 1 o g a v> , d f U u Q o I j f'6' U O O j —J 1 ? N o m m c _ = E c Q Y OV D Ce Q c :° V m :° 0. Cl) m .2 m Zi Z Z a a 0)a U t EE 1 wa2 co z LN o N -0 W Z .N U 0 O d a) Ct Z d o c z° z 0 y = N o .Io o z I CL O 0. to o m y = ? E N p ZI J 2 a) D Li • r _ Na) h d O M K E ' n J f) U ^ o 0 N J N 1 \ Q a I' f I— 1 _ y J 'E I m re E D a) C i 1 .-0 I CO cc Q Y L. °� o Q 0 a zl z o Q y U o) r// E J m E Z I iI z O a,0O• > p _1 , ya H z z z m co) >- >- >-O Q Z r G Z N N o W O N O O m cu 0 Q o co E E E z a m Z 2 ° € 3ci m J > °' p .`7 o�a N Z Q a d v 2 W al OLL d O O w ° = co - ! — W 0 H U 0 > E I .Q E ' 5 a '� o ) y 0 1 W Q o. y a m a y 0 a) L Ti C a) 0 0 a 2 I r p f- 3 JGH 3 a 3 U a� U U Page 1 of 1 Schwartz, Guy L (DOA) cT 1 D 10 13 9 From: Ohlinger, James J [James.J.Ohlinger @conocophillips.com] Sent: Monday, November 01, 2010 9:15 AM To: Schwartz, Guy L(DOA) Subject: RE: 3J-15 L1-02 (PTD 210-138) (PTD 210-139) We have finished 3J-15, and did not drill the 3J-15L1-03. I'll have a schematic shortly. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, October 25, 2010 2:18 PM To: Ohlinger, James J Subject: RE: 33-15 L1-02 (PTD 210-138) (PTD 210-139) James, The changes to the wellplan for 3J-15L1-02 (PTD 210-138) are acceptable as they stay within 500' of the original BHL per 20 AAC 25.015 (a)(2). The PTD for 3J-15L1 Q (PTD 210-139) will be withdrawn at your request. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James 3 [mailto:James.J.Ohlinger @conocophillips.com] Sent: Monday, October 25, 2010 9:59 AM To: Schwartz, Guy L (DOA) Subject: 33-15 We're looking at modifying the L1-02 lateral and dropping the L1-03. Schematic attached. James Oh-anger CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-748-1051 cell 11/1/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, October 25, 2010 2:18 PM To: 'Ohlinger, James J' Subject: RE: 3J-15 L1-02 (PTD 210-138) (PTD 210-139) James, The changes to the wellplan for 3J-15L1-02 (PTD 210-138) are acceptable as they stay within 500' of the original BHL per 20 AAC 25.015 (a)(2). The PTD for 3J-15L1-03 (PTD 210-139) will be withdrawn at your request. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James 3 [mailto:James.J.Ohlinger @conocophillips.com] Sent: Monday, October 25, 2010 9:59 AM To: Schwartz, Guy L(DOA) Subject: 33-15 We're looking at modifying the L1-02 lateral and dropping the L1-03. Schematic attached. James Ofiinger CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-748-1051 cell 10/25/2010 6 t:-,\ InsEn 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 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3J-15L1-03 ConocoPhillips Alaska, Inc. Permit No: 210-139 Surface Location: 1140' FSL, 565' FWL, SEC. 3, T12N, R9E, UM Bottomhole Location: 1048' FNL, 591' FEL, SEC. 3, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3J-15, Permit No 185- 289, API 50-029-21497-00. Production should continue to be reported as a function of the original API number stated above. 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. cer-ly, Daniel T. eamount, Jr. Chair DATED this Sday of September, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA a Z G'�'��' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ei6 ,k1 ' : ,x F.; i. , , , 20 AAC 25.005 la.Type of Work: • lb.Proposed Well Class: Development-Oil 0 'Service-Winj ❑ Single Zone Q el c.Specify if well is proposed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3J-15L1-03 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9175' TVD: 6422' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1140'FSL,565'FWL,Sec.3,T12N,R9E, UM • ADL 25630 • Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1064'FNL, 1210'FEL,Sec.3,T12N,R9E, UM 2563 10/6/2010 Total Depth: 9.Acres in Property: 14.Distance to 1048'FNL,591'FEL,Sec.3,T12N,R9E,UM 2560 Nearest Property: 15600 ' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 74 feet 15.Distance to Nearest Well Open Surface:x- 519545 • y- 6002823 ` Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3K-08,1200 16.Deviated wells: Kickoff depth: 8500• ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95° • deg Downhole:4233 psig • Surface:3623 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1070' 8105' 6255' 9175' 6422' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 8659' 6746' none 8409' 6562' none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 200 sx AS II 104' 104' Surface 4009' 9.625" 1300 sx AS III,325 sx Class G 4039' 3486' Intermediate Production 8470' 7" 360 sx Class G, 175 sx AS I 8500' 6630' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8047-8064',8235-8254',8274'-8311' 6305'-6316',6439'-6450',6465-6491' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program IN 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-110 Printed Name V. Cawvey Title Alaska Wells Manager °� Signature j Phon 265-6306 Date 1�3l�ly Commission Use Only l / Permit to Drill API er: Permit Approval See cover letter Number: r2—/0 .9C7 50- L��7 (�3 .Date: /t( c (`D for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: 'iK-y00Q s� 4OP /ej'{"' Samples req'd: Yes ❑ o 7 Mud log req'd: Yes ❑ No [r Other: - /1 ,i4.4 7- H2S measures: Yes ['+�No ❑ Directional svy req'd: Yes Q/ No ❑ APPROVED BY THE COMMISSION �� ) p DATE: � � � (20 ,COMMISSIONER Form 10-401 R vised 7/2009 This permit is valid 4 n t e e f roval 20 AAC 25.005(g)) Submit in Duplicate v. Permit to Drill Summary of Operations KRU 3J-15L1, 3J-15L1-01, 3J-15L1-02, 3J-15L1-03 Laterals Coiled Tubing Drilling Overview: The 3J-15 well is in an area that contains many sealing and highly baffling faults. The result of this is lower than expected oil recovery as oil resource is not being adequately produced from nearby fault blocks that have injection support with little or no production off-take. The scope of this project is to drill four CTD laterals out of the 3J-15 motherbore in order to target these areas of under-produced oil resource in the Kuparuk A-sand. Pre-rig work will be performed to allow CTD while maintaining the parent well's original A-sand completion. This will involve cement squeezing and abandoning the C-sand interval in the parent well which currently produces approximately 75 BWPD and zero oil. The sidetrack will utilize a monobore whipstock to conduct a dual string exit through the 3-1/2"tubing and 7" liner. The top of the whipstock is planned for 8,110' MD within the straddle,with Packers set at 7972'and 8144' MD. The 3J-15 motherbore completion will be retained by use of a flow through whipstock to maintain the original area. The first CTD lateral will target the A2 sand and will be drilled across the large south to north fault into the block containing the 3K-08 injection well. The second lateral will target the A3 sand and will kick out of the first lateral. It will run parallel to the first lateral so that both A-sands will have sufficient reservoir exposure on that side of the fault. The third and forth laterals will kick out of the first lateral on the west side of the south to north fault to increase exposure in both the A2 and A3 sands. Approximately 5,550 ft of total hole will be drilled and the productive intervals will be completed with slotted liners. The 3J-15L1 is planned for a 2-3/8" slotted liner with a liner-top aluminum billet for the KOP for the L1-01 lateral at—9,950' MD. The 3J-15L1-01 is planned fora 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-02 lateral at—8,700' MD. The 3J-15L1-02 is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-03 lateral at—8,500' MD. 3K-12L1-03 will be completed with 2-3/8" slotted liner from TD to—8150' MD in the original well bore. Operational Outline -S4 3/a — 3 03 Pre-Rig Work • Slickline: A-sand SBHP,pull TPI from AVA, dummy GLV's,MIT-IA Drift w/dummy whipstock, • E-line: Run GR/CCL jewelry log/tie-in log(7900' to 8200' RKB). Set 2-7/8"HES "FasDril"Composite Bridge Plug(CBP) in the tubing tail @ 8,161' RKB. Con firm injection into the C-sand interval. • Slickline: Bail in sand with a barite cap. • E-line: Shoot holes in the 31/2"tubing 8020' —8030' RKB, and 8110' —8120'. • Coil: Lay in cement plug from sand plug up to the 3-1/2"Cameo Production Mandrel @ 8010' RKB. • Slickline: Tag TOC and PT to 1500 psi. • Coil: Mill out cement, sand/barite plug, and CBP • Slickline: Run dummy whipstock • 0: Set BPV,prepare Wellsite for rig arrival Page 2 of 5 9/7/2010 t EE' L Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU BOPE and test 2. Set top of whipstock at 8,110' ELM 3. Mill 2.80"window at 8,110'; dual string exit 3-1/2"x 7" 4. 3J-15L1 Lateral a. Drill a 2.70"x 3"bi-center lateral to a TD of 11,050' MD b. Run the 23/8" slotted liner to TD with an aluminum liner top billet at—9,950' MD. 5. 3J-15L1-01 Sidetrack a. Kick off of the aluminum liner top billet at 9,950' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 11,100' MD c. Run the 2%" slotted liner from TD with an aluminum liner top billet at 8,700' MD. 6. 3J-15L1-02 Sidetrack a. Kick off of the aluminum liner top billet at—8,700' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,475' MD c. Run the 2%" slotted liner from TD with an aluminum liner top billet at—8,500' MD. 7. 3J-15L1-03 Sidetrack a. Kick off of the aluminum liner top billet at—8,500' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,175' MD - 6 H-e.P + si a' "moo- (TOL. ) rip Post-Rig Work `T' Csot ) 1. Install GLV's 2. Obtain SBHP 3. Produce to system 7.14f-10 Mud Program • Chloride-based Biozan brine (8.9 ppg)for milling operations, and chloride-based Flo-Pro mud (--9.20 ppg) for drilling operations. • There is an SSSV installed in 3J-15 so we may not have to load the well with completion fluid to deploy the 2-%"slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind &Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD - 3J-15L1 9,950 11,050 2%', 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-01 8,700 11,100 2% 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-02 8,500 9,475 2%',4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-03 8,105 9,175 2%",4.7#, L-80, ST-L slotted Page 3 of 5 9/7/2010 t`-) l r\ k !` Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Existing Completion Details: Category OD Weight; Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 65 H-40 0 104 1640 670 Surface 9 5/8" 36 J-55 0 4,039 3520 2020 Casing 7" 26 J-55 0 8,500 4980 4320 Tubing 3 1/2" 9.3 J-55 0 8,152 6,980 7,400 Tubing _ 2 '/8" 6.5 J-55 8,152 8,166 7,260 7,680 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure is 3623 psi assuming a gas gradient to surface based on the potential pressure of an equivalent 13.0 ppg mud weight. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 3J-15L1 14,650' 3J-15L1-01 14,650 3J-15L1-02 15,600 3J-15L1-03 15,900' • Distance to Nearest Well within Pool (toe measured to offset well 3K-08) Lateral Name Distance 3J-15L1 1200' 3J-15L1-01 1200' 3J-15L1-02 1200' 3J-15L1-03 1235' Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure 3J-15 is currently completed in both the C and A sands as a single-selective type completion, and had a static bottom hole pressure for the C-sand of 2302 psi (7.1 ppg EMW), and the A-sand was 2049 psi (6.4 ppg EMW). 3K-13 has been shut in, and recently measured 4247 psi (12.5 ppg EMW)on August 31St. 3K-08 has also been shut in from injecting water and it measured 4194 psi (12.3 ppg EMW, June '10). Similar pressures are expected as the laterals are drilled. Page 4 of 5 9/7/2010 Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Hazards • Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 9.2 ppg mud system and annular friction will supply enough pressure to overbalance the expected reservoir pressure. Choke pressure can be applied to if higher pressures are encountered as we near the surrounding injectors. • Well 3J-15 has 170 ppm H2S as measured on Dec. '09, and is the maximum H2S level on the 3J pad. All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD)techniques will be employed to provide constant bottom hole pressure by using 9.20 ppg drilling fluid in combination with annular friction losses and if needed applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 23/8" BHA will be accomplished utilizing the 23/4" pipe rams and slip rams. Well 3J-15 does have a SSSV, so the well may not have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off'conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 2050 psi 2050 psi Mud Hydrostatic(9.20 ppg) 3000 psi 3000 psi Annular Friction 770 psi 0 psi Mud`+Annular Friction 3770 psi 3000 psi (no choke pressure) (overbalanced (overbalanced -1720 psi) -950 psi) Target Pressure(11.5 ppg) 3745 psi 3745 psi Choke Pressure Required 0 psi 745 psi to Maintain 11.5 ppg Example: Using the 3J-15 SBHP from July'08 with a reservoir pressure of 2050 psi at 6290 TVDss (6.3 ppg EMW). While drilling and circulating at 1.5 bpm with 2"e-coil, head from the 9.20 mud (3000 psi), plus an estimated 770 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 3770 psi BHP (11.57 ppg EMW)and overbalance the reservoir by-1720 psi. When circulation is shut down, the mud will still be overbalanced to the reservoir pressure. However maintaining -745 psi at surface when the pumps are shut down will maintain a constant 11.5 ppg EMW to promote wellbore stability. Page 5 of 5 9/7/2010 c 2 as cn co 0 ,c 0, Co U) 2 < a b ,,,, -c-rs co CCI . • r-- 0 , . c.! .--e---; io as -c . : C— — co i'-- as . , . , Co c." -I 3 o) ..,... c:, ■ ' CO 0 CO CO c, H 00 ---, 6 ? " 45 < LO , . CO 0 ,— 10 C '----0 . . Z J I-- =3. . . 0) r- - Ia. N- H . N— E -J oI -E- , , . ib CO p Il ''a5 a) •:r Y :.. , . . 0 co ^ al . . . , CC Cs1 _j :_1 I— =I . . , . 't _ b ca csi I'Ll , . -co —- cC 0 - co y —. . : . . . (I) co — Q , . o Co o , , . c., "co 4 ,- oz) y "I : ■ CO 0 :,4- r: n rc ±-_.• , Y c = ) co CO co @.) ,r i..... ..__. . CU „ „ , . . w :5 Y Y @) as op Lo Do , , u_ . 1) CC I- -o Co Cs4 11) 0_ L'..-Y CO CC Ill co -2 c ., , u, r--- D 2 41 @ Z.0 H " 0 co a) 0) c -0 co a co r- r. ea c.) a) ,- @ E -u..1 4-- ©@ E -2- 5:5, -0_co • > D o — U) LL.1 u) as 02 ,. CC o -o 2 o_ ,-- 0 ,-..,, .,'. co c) cr) co - cx J. C6 a 7, „ CO op 0 , a. m(-) CL LL .«.' . . . 0 0 0 CO . . a_ _1 . o_ 0 ,, 0 ca a qt E ',;.= Z1 1 E < ';`,' E c . , , , . . cc Co (CO) s— I CO > CC CO ii • ' „ , . „ I- oi c_.) 1--- Co LL (3 < no (_) cs, •cs.t CV Cs! IT) tri N N co co o ._ c , . ....... o) Y. ,- ,-- Co Co Co h_ oo co CO Co c:, c:, c:i , , / / g b , 0 - c7, co i 0 H _ ' — i \\„\„, 0) 0 0 2 2 Y EL EL Et PI. "•. '‘: / , i 1 1 mg q lis ill ,* ,. ,.. 1.0 .,n I 1 t b - $ -i ,t,..., , . ,,.... ,E k, g 11 r...-k 111 ,11 t.;"II lli ;,,. 4 -.:-.,. 1 i, ,.,. , ....' 1 It w ill - -__-__-- _-_ --_-____- -- -_..___-..__ -_-_- rtv Ts f. . . , ,- •- 0 IT! 2 $ _i I- C) _ / I 1 I CD U) I 0 --I--- a) o 0) o @.) oc o s- @.) • In -a-) ca 2 ti) En @.) o E.,1 .,- ,_ 0 a Lo a o cn CD co CO 0 A 0 "al 2 o Lo c a) -cii '17)• ca. u) _ 4t if) o. •- t ‘-- co b a) .,-- csi o 1-01 o 4t • cr os 0 % E 0_cn op - co OD .rs' ris 2 , cc -60 u) co co 2 CL) a) • Cs1 < 03 (.0 0 <-- <-- ORG1NAL. KUP 3J-15 `--stem. 1i r1;.::,-4.' ,',7,--,Conoco Phillips ips -., Well Attributes Max Angle&MD TD {,3514.InC.' 'S Wellbore AP W WI Field Name Well Status Ind l") MD(ftKB) Act Btrn(ftKB) Calttoa,,-Ai S.,, 500292149700 I KUPARUK RIVER UNIT PROD 50.03 3,400.00 8,659.0 ^-°' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP 140 12/10/2008 Last WO: 33.91 2/50986 ._W£ILCn6A..::a 1, 0....-3.06,143-M _ - ._._.. Scn t .�� 'Annotaton Depth(ftKB) End Date An oration Last Mod By End Date Last Tag:SLIM I 8,329.0 I 8/52009 I Rev Reason:PULL PLUG,SET TPC ___ Imoshor 11/26/2009 • Casing Strings_.-- _ String OD String ID Set Depth Set Depth(TVD) String Wt String Casing Description (in) (in) Top(f1KB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd s z h ; sa: -,.,,,-.CONDUCTOR 16 15.062 0.0 104.0 104.0 62.50 H40 3",',... SURFACE 9 5/8 8.765 0.0 4,039.0 3,485.6 36.00 J-55 SURFACE(QC) 9 5/8 8.835 33.1 4,038.9 36.00 J-55 BTC PRODUCTION 7 6.151 0.0 8,500.0 6,630.3 26.00 J-$5 CONDUCTOR, PRODUCTION(QC) 7 6.276 30.8 8,499.6 26.00 J--BTC SAFETY VLV. .- Tubing Strings _. ;- _ _ 1,806 String OD String ID Set Depth Set Depth(TVD) String Wt String EL, Tubing Description (in) (in) Top(ftK6) (ftKB) (ftKB) (Ibs/B) Grade String Top Thrd TUBING 3 12 2.992 0.0 8,152.0 6,377.6 9.30 J-55 EUE8rdABMOD GAS LIFT, TUBING 27/8 2.4418,152.0 8,166.0 6,387.4 6.50 J-55 8RD EUE 2,309 Other In Hole(All Jewelry.Tubin"c Run&Retrievable,Fisl1,'etc.) Top Depth (TVD) Top Intl Top(ftKB)_(ftKB) (•) Description Comment _ Run Date ID(in) 1,806 1,805.4 9.41 SAFETY VLV Cameo TRDP-1A-SSA' 4/16/1986 2.812 2,309 2,279.6 29.63 GAS UFT CAMCO/KBUGl1/GLV/BK/.156/1331/Comment STA 1 8/17/2009 2.875 SURFACE, 4,039 4,545 3,8292 44.79 GAS UFT CAMCO/KBUG/1/GLV/BK/.156/1319/Comment STA 2 8/17/2009 2.875 5,975 4,849.0 44.59 GAS UFT CAMCOIKBUG/1/GLV/BK/.188/1344/Comment STA 3 8/1812009 2.875 GAS LIFT, 4.545 6,838 5,462.8 44.67 GAS LIFT CAMCO/KBUGI1/GLV/BK/.188/1329/Comment STA 4 8/18/2009 2.875 IF7,276 5,771.1 45.95 GAS LIFT CAMCO/KBUG/1/DMY/BK!//Comment STA 5 8/18/2009 2.875 GAS LIFT, 5,975 - ` 7,592 5,989.6 46.24 GAS LIFT CAMCO/KBUG/1/OV/BK/25//Comment STA 6 8/18/2009 2.875 7,912 6,210.7 46.21 GAS LIFT MERLA/TPDX/1.5/DMY/R4////Comment:STA 7 5/172009 2.875 jJi 7,958 6,242.5 46.19 PBR Baker 4/16/1986 3.000 GAS LIFT, 6.838 E 7,972 6,252.2 46.18 PACKER Baker'FHL' 4/16/1986 3.000 € =:,''- 8,010 6,279.7 47.07 PRODUCTION CAMCOMBUG/1/DMY/BK///Comment CLOSED STA 8 4/16/1986 2.875 GAS LIFT.,276 8,130 6,362.0 45.51 NIPPLE AVA BPL Ported Nipple 4/16/1986 2.750 7 8,130 6,362.0 45.51 SLEEVE-0 235"TPC NEW STYLE w/2.31"ID 11/8/2009 2.310 °. 8,144 6,372.0 45.33 PACKER Baker'FB-1' 4/16/1986 4.000 GAS LIFT, - _-_ 7,592 8,157 -6,381.1 45.16 NIPPLE Cameo'D'Nipple NO GO 4/16/1986 2.250 k.::;.''�' 8,165 6,386.7 45.06 SOS Cameo 4/16/1986 2.441 GAS 7,912 Llai'- 8,166 6,387.4 45.04 TTL --- 4/16/1986 2.441 Perforations&`Slots: . Shot " PBR,7.958- - Top(11/0) Btm(TVD) Dens Top(ftKB/ Blm jRKB) (ftKB) (ftKB) Zone Date (sh--- Type Comment 8,047 8,064 6,304.6 6,316.2 C-1,UNIT B, 4/15/1986 12.0 IPERF 5"HJ 11 Csg Gun,120 deg ph PACKER,7,972 - 3J-15 8,238 8,2456,438.7 6,443.7 A-3,3J-15 4/11/1988 4.0 REPE. 2 1!8"EnerJet,90 deg ph TION, `' 8245 8,246 6,443.7 6,444.4 A-3,32-15 4/11/1988 5.0 REPE...2 1/8"EnerJet,90 deg ph PRODUC 6,619 8,246 8,252 6,444.4 6,448.7 A-3,32-15 4/11/1988 4.0 REPE...2 1/8"EnerJet,90 deg ph 8,252 8,253 6,448.7 6,449.4 A-3,3J-15 4/11/1988 5.0 REPE...2 1/8"EnerJet,90 deg ph IPERF, -fir 8,253 8,254 6,449.4 6,450.1 A-3,32-15 4/11/1988 4.0 ROPE-..2 1/8"EnerJet,90 deg ph 8,067-8,061 i- - p 8374 8,311 6,464.6 6,491.4 A-2,3J-15 4/15/1986 4.0 IPERF 4"HJ II Csg Gun,90 deg ph NIPPLE,ant, - Notes:General&SafetY- SLEEVE-O,_ ,�.. _ 8,130 End Date - Annotation _ 1/25/1989 NOTE:WAIVERED WELL IA x OA COMMUNICATION PACKER,8,144 -- � L4 NIPPLE,8.157 a SOS,8,165- TTL,8,166 `. REPERF, - - 8,238-8,245 _ REPERF,6,245-8,246 REPERF, 8,246-8,252 REPERF, W 8,252.8,253 --. REPERF, --- 8,253-6,25/ FEW. '.. 8,274-8,311 1 PRODUCTION, 8,500 TO,8,659 0 R [-GINA-L---- conochi1Iips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3J Pad 3J-15 3J-15L1-03 Plan: 3J-15L1-03_wp01 Standard Planning Report 30 August, 2010 BAKER HUGHES HES • 't, t ConocoPhillips ' ii ii,onocoP 11111 3s Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) - Site: Kuparuk 3J Pad North Reference: True Well: 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-03 Design: 3J-15L 1-03_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3J Pad Site Position: Northing: 6,002,422.64ft Latitude: 70°25'4.020 N I. From: Map Easting: 519,544.60ft Longitude: 149°50'26.870 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.15° Well 3J-15 Well Position +N/-S 0.00 ft Northing: 6,002,822.60 ft Latitude: 70°25'7.954 N +E/-W 0.00 ft Easting: 519,544.80 ft Longitude: 149°50'26.833 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.10ft Wellbore 3J-15L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2010 8/26/2010 17.00 79.89 57,351 Design 3J-15L1-03_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,500.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -40.10 0.00 0.00 53.08 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,500.00 75.91 42.58 6,402.95 3,077.17 3,498.57 0.00 0.00 0.00 0.00 8,570.00 72.73 56.74 6,421.96 3,120.71 3,549.74 20.00 -4.55 20.24 105.00 8,651.68 87.00 64.84 6,436.32 3,159.71 3,619.75 20.00 17.47 9.91 30.00 8,751.68 85.98 84.85 6,442.50 3,185.67 3,715.59 20.00 -1.02 20.01 93.50 8,861.68 90.00 106.50 6,446.40 3,174.84 3,824.31 20.00 3.65 19.68 80.00 8,951.68 94.59 123.93 6,442.78 3,136.71 3,905.34 20.00 5.10 19.36 75.00 • 9,175.00 95.37 79.09 6,422.37 . 3,093.42 4,117.72 20.00 0.35 -20.08 273.00 8130/2010 3:32:36PM Page 2 COMPASS 2003.16 Build 69 ORG1NAL • r ConocoPhillips Irri" ConocoPhillhps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site: Kuparuk 3J Pad North Reference: True Well: 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-03 Design: 3J-15L1-03_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N!-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,500.00 75.91 42.58 6,402.95 3,077.17 3,498.57 4,645.45 0.00 0.00 6,005,908.61 523,034.95 TIP/KOP 8,570.00 72.73 56.74 6,421.96 3,120.71 3,549.74 4,712.51 20.00 105.00 6,005,952.29 523,086.01 2 8,600.00 77.94 59.81 6,429.55 3,135.96 3,574.42 4,741.40 20.00 30.00 6,005,967.59 523,110.64 8,651.68 87.00 64.84 6,436.32 3,159.71 3,619.75 4,791.90 20.00 29.22 6,005,991.46 523,155.90 3 8,700.00 86.46 74.50 6,439.09 3,176.44 3,664.92 4,838.08 20.00 93.50 6,006,008.31 523,201.03 8,751.68 85.98 84.85 6,442.50 3,185.67 3,715.59 4,884.13 20.00 92.95 6,006,017.67 523,251.67 4 8,800.00 87.71 94.37 6,445.17 3,186.00 3,763.77 4,922.85 20.00 80.00 6,006,018.12 523,299.85 8,861.68 90.00 106.50 6,446.40 3,174.84 3,824.31 4,964.55 20.00 79.47 6,006,007.13 523,360.40 5 8,900.00 91.98 113.91 6,445.74 3,161.62 3,860.23 4,985.33 20.00 75.00 6,005,994.00 523,396.36 8,951.68 94.59 123.93 6,442.78 3,136.71 3,905.34 5,006.43 20.00 75.13 6,005,969.21 523,441.53 6 9,000.00 95.02 114.24 6,438.72 3,113.34 3,947.37 5,025.99 20.00 -87.00 6,005,945.95 523,483.61 9,100.00 95.47 94.16 6,429.49 3,089.03 4,043.40 5,088.18 20.00 -87.81 6,005,921.90 523,579.70 9,175.00 95.37 79.09 6,422.37 3,093.42 4,117.72 5,150.23 20.00 -89.67 6,005,926.48 523,654.00 TD 8/30'2010 3:32:36PM Page 3 COMPASS 2003.16 Build 69 t.'' i �' 1" L ConocoPhillips ConocoPhilllps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site: Kuparuk 3J Pad North Reference: True Well: 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-03 Design: 3J-15L1-03_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) ( ) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3J-15L1-03 t1 0.00 0.00 6,422.00 3,093.18 4,118.12 6,005,926.24 523,654.40 70°25'38.364 N 149°48'26.028 W -plan hits target center -Point 3J-15L1,L1-01,L1-02 0.00 0.00 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 70°25'40.594 N 149°48'42.203 W -plan misses target center by 6407.90ft at 8500.00ft MD(6402.95 TVD,3077.17 N,3498.57 E) -Polygon Point 1 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 Point 2 0.00 3,390.00 3,827.85 6,006,222.27 523,363.38 Point 3 0.00 3,342.19 4,141.76 6,006,175.29 523,677.38 Point 4 0.00 3,364.10 4,566.86 6,006,198.31 524,102.38 Point 5 0.00 3,634.87 5,057.60 6,006,470.33 524,592.36 Point 6 0.00 4,248.40 5,264.20 6,007,084.34 524,797.33 Point 7 0.00 4,120.44 5,630.91 6,006,957.35 525,164.34 Point 8 0.00 3,473.82 5,459.23 6,006,310.35 524,994.37 Point 9 0.00 3,155.39 5,223.39 6,005,991.34 524,759.39 Point 10 0.00 2,962.73 4,693.84 6,005,797.31 524,230.40 Point 11 0.00 2,940.35 4,060.72 6,005,773.27 523,597.40 Point 12 0.00 2,922.27 3,701.63 6,005,754.26 523,238.40 Point 13 0.00 2,607.00 3,404.79 6,005,438.24 522,942.41 Point 14 0.00 2,891.73 3,134.50 6,005,722.23 522,671.41 Point 15 0.00 3,168.08 3,398.23 6,005,999.25 522,934.39 Point 16 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 3J-15L1-03 fault 2 0.00 0.00 0.00 3,343.20 4,118.78 6,006,176.24 523,654.40 70°25'40.823 N 149°48'26.005 W -plan misses target center by 6427.22ft at 9175.00ft MD(6422.37 TVD,3093.42 N,4117.72 E) -Polygon Point 1 0.00 3,343.20 4,118.78 6,006,176.24 523,654.40 Point 2 0.00 3,088.33 4,057.12 6,005,921.23 523,593.41 Point 3 0.00 2,954.41 4,022.77 6,005,787.24 523,559.42 Point 4 0.00 3,088.33 4,057.12 6,005,921.23 523,593.41 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (••) ( ) 9,175.00 6,422.37 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,500.00 6,402.95 3,077.17 3,498.57 TIP/KOP 8,570.00 6,421.96 3,120.71 3,549.74 2 8,651.68 6,436.32 3,159.71 3,619.75 3 8,751.68 6,442.50 3,185.67 3,715.59 4 8,861.68 6,44640 3,174.84 3,824.31 5 8,951.68 6,442.78 3,136.71 3,905.34 6 9,175.00 6,422.37 3,093.42 4,117.72 TD 8130/2010 3:32:36PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL �� — t I : en T I N 8 �: s O K Ii Cr I I - N _ • I N O o b 1 V4 U M }- t M i -N o0 1 m v, Ws 5 , r ( i :8 ± i o h _�_ e i Sam H,'" :.g:IN \ I - .` _. vi • Q I-- sy Lw -I O • co co 11111111 4■,, -4 1_ O l O• . N = K + M N N ... O ON Q CO CO t-- I i 11 M M M M M M + M . 1 p V � •I o ( /3 OS)( t[uow() nos en d o 0 _l 1 K p } K f O 4>iii 2 Ya$§ 47 I I O a O a0 11 { 1 _ T . s z €— o I 4 s o s Y s7 z g- 'I I P s K I [ K R Y A 834.84.Ki ICI -__-1 ._.-_ -O •cvvvv•n ui c co 8D m 8888888 I5,T_ b .O 6M Oho 1 o.- ce M-, r — N K 0 o O I ! 2 ▪ 3 22���• 8880 p8888 - -___� '___ _K• . _;- �ONNN 6NN 1 _ YYMMO I o .. o;0. It ivva..nrnrnpppp�Y N .1- y.__..__ K m ij m m ,31 m N W M o M M M V ! _N _ -1 --___ 8 il) a T.J• 11 O.J- Q •,)gip K r • .. F ° m°m o m ° ti°2 *8 O O p> ' MM _ .+ J J j O� 4W1 _,O W _ W e 2vOy NVaMa��NybVy a�a��NR a K • O _ V 8(O -Ne I _ - b Z R o M K • 8 U Oi f2 8 88 O o r j///r1E' _ r rrW O O ! K• �- 0 n 8 8 2 8 888 b" e b b b b b a " . o' b 6 VI N VI N (J 00 07 m m m rn lanai ea$ueapni O O ? U p O (Ary .-NM'Q 6t,.1.-.- (U /3 OZ) todaQ +EO'uIan an.I,Y, „ r', IGINtk I_ 1 o ki Si . mI 0 I ( -o r _i o I f 8 mss- 0 • � 0 e� 1 I �i w• _�p��Q I I■`G C O A I I - 1 1 1 t a�° I I 1 o o>� T _0 1. 1 1 � o �I I �. • �S - , �.. I 0 . J I ! y' C ■Li { 1 e E o I I' Z-__ cc m▪ d �a]S I 3 1` 8 1 ill i / ' 1 8 ! � :i lV o 8 I o c o 1 1 o I i r- ;Y CI ° ( III i 8 I. 1 I d �i mN a 3 ; I I 1 ! ( 8 o 1 o i o 1 t ( s i/n�y r .. T . ..- - ' }- ...1 1 _ ?. ��li b - . .- j. '` 0�.. O C § O O O y0' • v' O O ryb? O r c� v. N O 8 ce , , . b . . v, v, v, of , , 4 N^i M , N N N N ' -. l� l0 �(nw/13 OSZ) (+)4aio /(-)41nos o a 0 V 2 3 ORIGINAL M Conoco Phillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3J Pad 3J-15 3J-15L1-03 3J-15L1-03_wp01 Travelling Cylinder Report 08 September, 2010 FASO BAKER HUGHES flRG ! NAL ConocoPhillips re' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3J-15 Project: Kuparuk River Unit TVD Reference: 3J-15 @ 74.00ft(Rowan 34) Reference Site: Kuparuk 3J Pad MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site Error: 0.00ft North Reference: True Reference Well: 3J-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3J-15L1-03 Database: EDM Alaska Prod v16 Reference Design: 3J-15L1-03_wp01 Offset TVD Reference: Offset Datum Reference 3J-15L1-03_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,500.00 to 9,175.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,114.11ft Error Surface: Elliptical Conic Survey Tool Program Date 8/30/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 75.00 8,100.00 3J-15 GyroData(3J-15) GYD-CT-CMS Gyrodata cont.casing m/s 8,100.00 8,500.00 3J-15L1_wp09(3J-15L1) MWD MWD-Standard 8,500.00 9,175.00 3J-15L1-03_wp01 (3J-15L1-03) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 9,175.00 6,496.37 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3J Pad 3J 06 3J 06 3J 06 Out of range 3J-101 -3J-101 -3J-101 Out of range 3J-101 -3J-101-3J-101 (wp07) Out of range 3J 15 3J 15 3J 15 8,516.72 8,575.00 218.44 85.03 168.86 Pass-Major Risk 3J-15-3J-15L1 -3J-15L1 wp09 8,524.93 8,525.00 1.25 0.76 0.55 Pass-Major Risk 3J-15-3J-15L1-01 -3J-15L1-01_wp07 8,524.93 8,525.00 1.25 0.76 0.55 Pass-Major Risk 3J-15-3J-15L1-02-3J-15L1-02_wp01 8,524.93 8,525.00 1.25 0.76 0.55 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/8/2010 9:46:29AM Page 2 of 7 COMPASS 2003.16 Build 69 ! GIN IA Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N l i Lubricator Et St Riser r ■nnular Blind/Shear 2" Pipe/Slip (CT) Pump into Lubricator _ �4� L • above BHA rams i i '1 L Choke 1 2-3/8" Pipe/Slip(BHA) I' Choke Equalize Manifold I 2-3/8" Pipe/Slip lip(BHA) I Kill ►/\D J L L . - - - 1 r Blind/Shear ' 2" Pipe/Slip (CT) I' 'I Choke 2 'I '1R-j-Swab Valves lis Wing Valves I L 'N-4- II Tree Flow Cross 1 r Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union ORIGINAL TRANSMITTAL rLLETTER CHECKLIST WELL NAME 1<1L PTD# 7°/0 /3 7 / Development Service Exploratory Stratigraphic Test Non-Conventional Well f� It6� y- 07_ FIELD: / `-A7 tt�c ace-1r' POOL: kr,,L. 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 –' i( 3 /s— (If last two digits in Permit No. p API No. 50- q . API number are �0� ` � (ir, - �� / 7 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. Rev: 1/11/2008 >I 1--1 CO U) N N o 5 o @ W 3 C N n Q CT Q C co o a) 3 H c 0 wo•- o O. 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