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210-107
New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 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. oa 1 Q - 4 © Well History File Identifier Organizing(done) ❑ Two-sided 11 II' II II II III ❑ Rescan Needed 1111111111 I III III RE CAN DIGITAL DATA OVERSIZED (Scannable) VColor Items: ❑ Diskettes, No. n ❑ Maps: 1,27 -eyscale Items: Oth � er, No/Type: P 1 v0 i ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: .c. OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: anilb Date: a /s/ rYi P Project Proofing 1111E 1111111 llH BY: MOM Date: a 5 ' /s/ p Scanning Preparation ___ __ x 30 =12_0_ + 11 = TOTAL PAGES 7/ (Count does not include cover sheet) 0 BY: Date: a. 5 /s/ I' Production Scanning 1 111111111111111 Stage 1 Page Count from Scanned File: 7 a, (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: (/ YES NO BY: AIM Date: a/g J /q. /s/ 144p 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 11111111111 11111 ReScanned 1 1111111111 IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 1 19/')9/9!111 1/1/.,11 u;,*,....C;I,.!`....e.o..,... l..,. 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W N ? * 0 N W * W _ O. -0 S 0 0 w - 0 a n -0 " Z O v 3 rN 0 D O co„. IV S Cl) G > �. 0 - 50 , 50 s w c� = m y 0= w v 0 = v v 0 _ 0 c s -a 0 c s a 0 c s Q 0 ?!� 0_ 0 _ x a� y T1 p) �. 1'I y �. �t p) g. TI w O. CD O fD (D N ,.■r `` m m m , m m , 9O ,. r C1)- o 0 r coi `-, r ,o o �0 r- o 0 r o 0 d m m 4 in v) u) y - `` cnj - G7o - No o (7a - 0zn -c3 o o Y o o o y r _- r co o y 4., ...., ,,i...) ..,.., O a a --0 U Cr C h 0 I H til PC Er iv C Page 1 of 1 Schwartz, Guy L (DOA) From: Eller, J Gary [J.Gary.Eller @conocophillips.com] Sent: Friday, September 03, 2010 12:51 PM To: Schwartz, Guy L(DOA) Cc: Gantt, Lamar L; Cawvey, Von / o� Subject: KRU 3N-16A Drilling Options Attachments: 3N-16A CTD Options 9-3-10.pdf Guy-As we discussed earlier today, the crystal ball is very murky on the future of the CTD laterals in KRU 3N- 16A. I wanted to get you up to speed as I can regarding the current status and possible drilling scenarios that may occur over the weekend. The attached file shows a wellbore schematic as it presently exists plus two possible scenarios. Current Status-The AL1 lateral has been drilled at lined to 9755' MD. The AL1-01 lateral was drilled from 8610'-9240', but severe lost circulation and related hole collapse problems have prevented us from running liner. We're currently trying to clean out a portion of the AL1-01 lateral to simply run liner and keep what we drilled in AL1. We have been completely unable to clean the AL1-01 out past 8730' MD, so a substantial portion of what is currently called AL1-01 will become a plugback. Scenario#1 -This scenario assumes we can clean out the existing lateral and get liner down to the junction of the AL1 lateral. If that is the case, PB1 will exist from-8630'-9240' MD. We'll set another whipstock and redrill the AL1-01 lateral north. Scenario#2- I we r- ' -• - o c can out or run liner down to the AL1 junction, we would like to set a cast iron bridge plug (CIBP)to completely isolate the boreholes we have drilled thus far. These boreholes would be renamed PB1 andPB2. We would set another whipstock and redrill AL1 and AL1-01 north. The purpose of the CIBP is to at least temporarily shut off losses to the plugback boreholes so that drilling can commence from the new window. Prior to going into the holiday weekend, I would like to receive approval from the AOGCC to set a CIBP to isolate the existing boreholes if we're unable to get liner in place. Otherwise, I think the northern directional plans that have been approved (210-107 &210-108)are easily within 500' of these redrills, so no special approval should be required. Thanks, and please call if we need to discuss. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 9/3/2010 0 0 b a— 2 ••••/— i.; b Ct. i•-': 0 co ,— 2 co C.n ■ L' r'-'' — <c <7 1:1 0 Ct. 2 D .... • -F. , co . . co . _i • . © • . 0 • H • I . • . a. • — • • • _, a • • • Li,' • • 2 Cr ro.0 0 . ,..i . - 2 co • • i, • ,2 7,,= >, 0 N 2. Ct.© 2 • © co a, o o- [o • w r-- > D a, , in Li, 0 C71 i.., . C' g D ar • co C./) 2 ..\.:: 8 8 8 , .x .g 1 E 42 E E co© at -c,N= 0= . •E ,0 co o3 m O 8:'—x r;22 X 0 6 o 0 oo, & & ,,..... i 4- Z.,.. -,.1- N. i,, . . ',—7 _,'6 1 co . .— A A A A on M A A A A A .,......‘ . . , . . . . . . . . . . . . . , . . . . . . . . . . . . . • . . . . . . . . . . . : : . . • . . , . . . . . . . . . . . , • • : : . • . . • I . •/•::::,/ . . . ... ... ! .. .• I .s.: ..., .. ....,.... . • • • • ...,../ . ...,... .,._ 1 , .. .. .... • . . „ ....... , , __is ,,, ,, ,„ 1:1 I • ... _.„. .., ' 1 * 0 .— 3,— Z.,'"I'''' 0:1 .,,,,, , C co cn W (..) 2 22 CO - 1 S') o 0 .0 0 0 2 o co un an .2,0 at 2 0 oo co 2 o F. g co- r- .— Iii b o.b CO o ar al-in a I Zo CO Z cn© 0 0 co 0 co co(1) Y on m CI H nr" Page 1 of 2 Maunder, Thomas E (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, June 29, 2010 8:22 AM '°7 To: Greener, Mike R. p / O r / 0 T Cc: Lowry, Scott L; Maunder, Thomas E(DOA) _ �GA thst Subject: RE: 3N-16A liner cementing •, � Mike, Per 20 AAC 25.030(6)&(7) the intermediate liner doesn't need to be completely cemented but the liner lap interval must be pressure competent. Provided the liner top packer tests you are good to go.. This liner lap will not be subjected to the injection pressure as the seal bore will be above it and see only IA annulus pressure_ A CBL is needed to verify the cement quality and determine TOC_ Thanks, Guy Schwartz Senor Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Tuesday,June 29, 2010 8:05 AM To: Greener, Mike R.; Schwartz, Guy L(DOA) Cc: Lowry, Scott L Subject: RE: 3N-16A liner cementing Correction to information below. Expected TOC is 650' below the TOL NOT the window. Mike Greener From: Greener, Mike R. Sent:Tuesday, June 29, 2010 6:44 AM To: Schwartz, Guy L(DOA) Cc: Lowry, Scott L Subject: 3N-16A liner cementing Ran 3-1/2" liner to TD at 8,190' MD / 6,478' TVD. Cemented ' ner with 119 bbls of 15.8 ppg cement. Proceeded cement with 40 bbl chemwash and then 40 bbl mudpush. Cement excess at 35%. 7/4/2010 Page 2 of 2 Bump plug with no issues. Bled off and floats held. Release from hanger. Circulate hole clean and recover 40 bbls of chemwash and 20-25 bbls of mudpush then 10 ppg mud but no cement. Liner lap is 209' inside 7" casing which is 5 bbls. Expect TOC should be about 650' below 7" window. FIT on window was 12 ppg. We have not set the liner top packer. Currently we are laying down some of our 4" DP. Do we need to squeeze the liner top considering how close the estimated TOC is to the liner top? I will call to follow up. Mike Greener 7/4/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener @conocophillips.com] Sent: Monday, June 28, 2010 9:55 AM To: Schwartz, Guy L(DOA); Maunder, Thomas E (DOA) Subject: 3N-16A as of 6/28/2010 Attachments: Greener Mike.vcf; 3N-16A Rig Surveys(NAD 83).xls We have drilled to a TD depth of 8,190' on ST #4. Attached is the directional. Read the tab 3N-16A. We are now in the process of running a 3- 1/2" liner to complete the well. Mike Greener 7/4/2010 Page 1 of 2 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener©conocophillips.com] Sent: Tuesday, June 22, 2010 9:01 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: 3N-16A status at 15:00 hrs 6/21/2010 Attachments: Greener Mike.vcf; 3N-16A Rig Surveys(NAD 83).xls;wellbore with ST.jpg Wellplan is now #13. Attached is the new wellplan. The plug backs are in the file also. Cartoon attached showing the different sidetracks. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, June 22, 2010 7:35 AM To: Maunder, Thomas E (DOA); Greener, Mike R.; Schwartz, Guy L(DOA) Subject: RE: 3N-16A status at 15:00 hrs 6/21/2010 Mike, Following up on your plan to mill a new window(I pasted in your earlier message). Is the BHL target still the same? We probably need to talk about all the correct naming of all the plug backs. I should be in all morning. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, June 21, 2010 7:42 PM To: Greener, Mike R.; Schwartz, Guy L (DOA) Subject: RE: 3N-16A status at 15:00 hrs 6/21/2010 Mike, Sorry, I was out of the office today. The answer to your original question, did you need to tag the first plug is NO provided it goes into place without issues. It would appear since you have proceeded on that you were successfully able to place both plugs. As I remember our discussion last week, the Kuparuk had not been penetrated which mitigates the need to tag. Good luck with this tar baby. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Mon 6/21/2010 3:22 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Subject: 3N-16A status at 15:00 hrs 6/21/2010 We have placed the two 500' plugs into the well with the bottom of the first plug at 7,600'. We are now POOH to PU a cement retainer which will be set at 4,900' in the 7" casing. We will squeeze with 50 bbls of 16.8 ppg cement. 7/4/2010 Page 2 of 2 My cell # is 350-3238 Mike Greener From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Monday, June 21, 2010 9:06 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: Status of 3N-16A as of 6/21/10 We attempted to get to bottom on ST #3 and we stuck our drillstring at +/- 7,700'. The HRZ appears to be running shale on us. We got the drillstring free and after consulting with the north slope AOGCC rep we proceeded to PU a 2-7/8" stinger to place two cement plugs in ST #3. During the run in of the 980' stinger on our 4" DP we stuck it at +/-7,800'. We stopped running in the hole as soon as we tagged up and the stinger stuck and packed off. After working it for a period we were able to establish circulation and we got the stinger free. We are currently placing the first cement plug at +/- 7,600'. It is sized to be a 500' plug with 50% excess. Do we have to tag this first lug before placing the second one on top of it? We are also going to place a retainer above the window in the 7" casing and squeeze the window. Plan forward is to mill a new window above the retainer and drill ST #4. Mike Greener 7/4/2010 7" casing Li Surface shoe @ 4,797' Whipstock —�� On tap of retainer deer 4,900' ST#4 •Whipstock' : ::�: �. ::•.. 4,950 -Ne..:• ::.:. Ir -....:•:•:•::.. ...:.:•:.:•:.:::::::•:•:.:::•:•:•:•:.:•. .::::•::;•::C8nt8fit�,y��.s... CIE @ 5,360' in 5.1.4,,liner ::::: :•':;.\:\ 8,197' 6,475' 7,682' 8,18 7,756' 8,260' ST #1 Page 1 of 1 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener @conocophillips.com] Sent: Thursday, June 17, 2010 6:18 AM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L(DOA); Chambers, Mark A; Lowry, Scott L; Alvord, Chip; Doyon 16 Company Man Subject: RE: Plan forward on 3N-16A Attachments: Greener Mike.vcf Thanks for the reply. The liner appears to be in the "old" hole (ST #1). We will follow the procedure in the plan forward for that scenario. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, June 16, 2010 4:19 PM To: Greener, Mike R. Cc: Schwartz, Guy L(DOA); Chambers, Mark A; Lowry, Scott L; Alvord, Chip; Doyon 16 Company Man Subject: RE: Plan forward on 3N-16A Hi Mike, Isn't this fun. As far as nomenclature goes, the original penetration (your ST 1)should be called 3N-16APB1. Your ST 2 doesn't sound of much consequence so I am inclined to ignore it, unless your directional or logging people got any new information. If you successfully cleanout what you call ST 3 and get 3-1/2" liner run and cement, then the well is set up for CTD. If the liner is stuck in what you call ST 3, then all the hole you loose will be 3N-16APB2. The follow-on phase will really depend on what the targets are when you attempt to drill the entire new wellbore. If the BHL remains the same, then you would be still drilling 3N-16A. If the BHLs change, then it is possible that a new permit will be needed. Good luck determining the options. Lets talk tomorrow to see how the path forward looks. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike.R.Greener @conocophillips.com] Sent: Wednesday,June 16, 2010 3:42 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L(DOA); Chambers, Mark A; Lowry, Scott L; Alvord, Chip; Doyon 16 Company Man Subject: Plan forward on 3N-16A See Attachment. Mike Greener 6/17/2010 PLAN FORWARD as of 6/16/2010 If the liner is in ST#1 (the old hole) 1. We will place a CIBP in the liner at+/- 5,350' MD. Wireline is acceptable. 2. Run in hole with a jet cutter on wireline and cut the liner at+/- 5,325'. 3. RIH and retrieve liner. 4. PU reamer with bullnose and motor and RIH to clean out to TD in ST#3. TD depth is 8,180' MD. 5. POOH and run 3-1/2"liner and cement same. Liner shoe needs to be less than 35' in length to stay in the`B" shale. 6. Cement needs to come to the liner top. If we do not circulate any cement off of the liner top then the liner top needs to be squeezed. If the liner is in ST#3 (the new hole) 1. We will place a CIBP in the liner at+/- 5,350' MD. Wireline is acceptable. 2. Run in hole with a jet cutter on wireline and cut the liner at+/- 5,325'. 3. RIH and retrieve liner. 4. PU cement retainer and RIH to 4,900' and set same in 7"casing. Squeeze ST and window with yet to be determined amount of cement. 5. POOH and PU whipstock and RIH. 6. Cut new window using yet to be determined new directional plan. Plan is dependent upon whipstock set depth. 7. Drill new ST#4 to planned TD. 8. Run and cement 3-1/2" liner. Liner shoe needs to be less than 35' in length to stay in the`B"shale. 9. Cement needs to come to the liner top. If we do not circulate any cement off of the liner top then the liner top needs to be squeezed. 3N-16A Plan as of 6/16/2010 Events to date Drilled original sidetrack(#1)from the 7"casing to 8,260' MD/6,417' TVD. During the running of the 5-1/2" liner we were unable to get pass 7,740' MD. We pulled out of the hole and picked up our BHA and during the clean up of the wellbore we inadvertently sidetracked at 7,682' MD (#2). We attempted to continue this new sidetrack(#2)but our BHA directional tools malfunctioned and the wellbore was drilled in the wrong direction to a depth 7,756' MD. After review it was determined to be able to keep drilling in the new ST(#2)we would have to obtain doglegs greater than 10 degrees to reach our objective. We then placed a cement plug in the well which failed to set up and which required a second plug to be placed. We were unable to get a solid KOP on the second plug and the decision was made to do an openhole ST(#3) at 5,195' in the original ST(#1). The new ST (#3)was drilled to a depth of 8,180' MD/6,465' TVD. The 5-1/2" liner was run with a 4-1/2" shoe (to assist entering the new ST(#3)). The liner was run to 7,528' MD where it became stuck. We have backed off from the liner hanger and are currently at the surface preparing to run a inclinometer to verify which ST we have the liner in. We will then RIH and jar on the liner in an attempt to free it. Late night 6/16/2010 we will POOH and run a gyro to do a backup verification on the liner placement. 7"casing Whipstock @4,960' 7,682' ST#3 8,180' S ST#1 T#2 7,766' 8,260' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ El WAG ❑ WDSPL ❑ No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Abend.: September 12,2010 210-107/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 August 26,2010 50-029-21593-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1561'FSL,30'FEL,Sec.29,T13N,R9E,UM August 28,2010 3N-16AL1 Top of Productive Horizon: 8. KB(ft above MSL): 60'RKB 15.Field/Pool(s): 519'FNL, 1721'FEL,Sec.33,T13N,R9E,UM GL(ft above MSL): 34'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 324'FNL,694'FEL,Sec.33,T13N,R9E,UM 9755'MD/6459'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-518371 y- 6013799 Zone-4 9755'MD/6459'TVD ADL 25521,25520 TPI: x-521970 y- 6011729 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-522995 y- 6011928 Zone-4 2103'MD/1993'ND 2556,2557 18.Directional Survey: Yes is No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700'MD/1700'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8165'MD/6460'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 249 sx CS II 9.625" 36# J-55 Surf. 4797' Surf. 3638' 12.25" 1350 sx AS III,350 sx Class G 7" 26.0# J-55 Surf. 5000' Surf. 3752' 8.5" 300 sx Class G,175 sx AS 1 2-3/8" 4.7# L-80 8166' 9755' 6517' 6459' 3" sptted liner 3.s_ 4. 3 Ir L-Po NGGG• Q/go_- 357x' GY7p` 70" J /lker P �/o y •SIo 24.Open to production or injection? Yes is 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) 3.5" 4703' none 8260'-8622'MD 6507-6514'ND 8623'-9752'MD 6514'-6459'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. v'r (iOiVj f DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 7142 Lftft • 1 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) September 18,2010 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No is Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE OCT 0 5 2010 ta Oil&GasCons.Carr ion REIMS OCT 05 kilt Aneherive Form 10-407 Revised 12/2009 CONTINUED ON REVERS S • it original only / -5/0 I ' (e°/;(('0 28. GEOLOGIC MARKERS(List all formations and markers wncountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1700' 1700' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A2 8419' 6526' 3N-16AL1 PB1 TD 9240' 6454' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 \\N\>,...._ Printed Nam V Caw Title: Alaska Wells Manager ��/��' Signature Phone 265-6306 Date V Sharon Allsup-Drake 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 1a: 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. 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O u) fn u) 6 u) 0 0 0 0 0 0 0 0 0 fn N O O O O o 0 • CW .. V Q m O co m m N V) co a I- O co 0 m N co m .- 4 r O a O O a �"� — 0 !` N (o co m 1. r r m m CO m m 0) m 0 0 0 r N N m i 0 co m m m m m m m m m a0 m m m m m m m m m m m 0 V O d (• N o_ 3N-16A Well Work Summary DATE SUMMARY 7/11/10 SET CATCHER SUB @ 4598' SLM, PULLED SHEARED SOV @ 4590' RKB AND SET DV. MIT IA TO 2500 ( PASS ). MIT TBG. TO 2500 PSI ( PASSED ON THIRD ATTEMPT). ATTEMPT TO DRIFT TBG. W/ 19' OF 2 5/8 DUMMY WHIPSTOCK DRIFT, TOOLS FALLING VERY SLOW @ 0-15' PER MIN. ONCE INSIDE LINER. 7/13/10 TAGGED WITH BAILER @ 8143' SLM. DRIFTED TBG & LINER WITH 19'x 2 5/8" DUMMY WHIPSTOCK TO SAME; TOOLS FELL SLOWLY, 50 FPM, THROUGH TOP 200' OF LINER. COMPLETE. 7/22/10 PERFORMED CEMENT BOND LOG FROM TAG DEPTH OF 8154'TO 4500'. PERFORMED JEWLERY LOG FROM 8154'TO SURFACE. TOP OF CEMENT IN LATERAL LINER FOUND AT A DEPTH OF 5564'. 7/23/10 PRE CTD PT SV, MV,SSV( PASSED ) DDT SV, MV, SSV ( PASSED ) DDT SSSV( FAILED ) 8/7/10 (PRE-RIG) STATE WITNESSED MITT- PASSED; (ROBERT NOBLE) 5c """ 8/9/10 MILL CEMENT FROM WIPER PLUG TAG @ 8177 CTMD TO 8210 CTMD, FP/3500 TO a SURFACE, BACK TOMORROW FOR UNDER- REAM CEMENT SHEATH, 8/10/10 Under-reamed from 8170'to 8211' CTMD. Freeze protected with diesel. Ready for SL / SI� dummy whipstock run. r 8/11/10 GAUGED TBG TO 2.68"TO 8174' SLM. DRIFTED TBG WITH 19' x 2.625" DUMMY WHIPSTOCK TO 8174' SLM. COMPLETE. 8/22/10 Mobilze rig from 3K pad to 3N pad. Excemptional Rig move. 8/23/10 Swapped skates on injector, Began BOP test. State wavied witness by Chuck Schvick. Accepted Rig @ Midnight. 8/24/10 Complete BOP test. (All Pass) Pumped Slack-cut 15 ft to find cable. Cut 700' off CT string. RIH with Dummy WS & Circ well over to milling fluid. 8/25/10 Set TOWS @ 8170' -P/U Milling BHA-BHI software problems (counter) -Start milling window from 8165'to 8170'-Continue milling formation to 8181'. Three reaming passing and clean dry run through window. POOH 8/26/10 RIH with build assembly, clean drift through window. Drill build section to 8345'. Tie into RA marker-correct Window depths: TOW 8170' - RA marker 8174' BOW 8175'. 8/27/10 Drilled ahead in All lateral. Poor shale section from 8700 to 8740'. 118 bbls losses in 24 hours. 8/28/10 TD lateral to 9755' - pump liner pill. Had two overpulls inside casing @ 7700'. RIH &circ B/U with heavy shale returns to surface. P/U Liner assembly and hard tag @ 8277'Ankerite area. POOH. 8/29/10 Lay down Liner, P/U clean out assembly with D331 bit. Troubled spots 8216', 8787'-heavy marble shales over shakers. Continue cleaning well, lots of culling coming over shakers all 3 wiper trips. Final wiper-lost full returns, Lay in Liner pill-WH pressure came back at window. Hold MPD While POOH. * 140 bbls losses in 24 hours** 8/30/10 P/U Liner assembly with 1.5 Degree bent sub, RIH to TD. Liner set 9755' -8622', RIH with Anchored Billet from 8622' -TOB 8611'. POOH, weekly function test of BOP's. 22 bbls loss for 24 hours. 8/31/10 Cut 25'coil and rehead. M/U Drill by BHA and drill past Billet @ 8609. Drill ahead to 8990. 24 Hr Fluid loss 76 BBIs 9/1/10 Drill to 9240', unable to get past 8250 on wiper from 9240. POOH to get clean out BHA. Get past 8250 but not 8480. POOH to decrease AKO setting. Lost 657 BBIs last 24HRs 9/2/10 POOH to dial down motor AKO from 2 to 1.3. Clean out to 8720. Trip for Bi Center to get past 8720 9/3/10 POOH drop Bi Center and P/U mill for clean out. 9/4/10 Completed FCO to 8700. POOH, M/U and run liner to 8683, TOL 8167 9/5/10 Complete Injector skate Change out, RIH with nozzle. Perform pressure tests. Pump Hi Vis pills to heal losses. 9/6/10 Complete pressure tests, Set whipstock @ 8147, Complete BOPE Test, Witness waived by Jeff Jones, AOGCC 9/7/10 Milled window#2. POOH and MU drilling BHA#19 for build section. RIH and start drilling build section. 9/8/10 Drilled build section. POOH and MU lateral drilling BHA. Drilled AL1-01 lateral to 8627' 9/9/10 Drilled AL1-01 lateral from 8627'to 9420'. 9/10/10 Fluid losses while circulating KWF with liner beads. Swap hole back to 8.6 ppg FloPro. Wiper trip to clean well. 3N-16A Well Work Summary 9/11/10 Landed liner for AL1-01 lateral. Displaced well to diesel from 8100'. 9/12/10 Rigged down and moved off 3N-16A. 9/13/10 RAN WIRE GRAB, BRUSH & MAGNET TO REMOVE METAL DEBRIS f/TBG. DRIFTED TO DEPLOYMENT SLEEVE WITH 2.62" DRIFT. MEASURED BHP @ 8100' RKB: 2564 PSI & FALLING. ATTEMPTED SET SLIP STOP CATCHER, ENCOUNTERED MORE FILAMENTOUS METAL DEBRIS. IN PROGRESS. 9/14/10 BRUSHED& FLUSHED f/SURFACE TO X NIP @ 4724' RKB TO CLEAR METAL DEBRIS. SET SLIP STOP CATCHER. PULLED DVs @ 4593' &3033' RKB. SET OV&GLV @ SAME. PULLED CATCHER. COMPLETE. ConocoPhillips Time Log & Summary We!Mew Web Reporting Report Well Name: 3N-16 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/23/2010 4:00:00 PM Rig Release: 9/12/2010 9:00:00 AM Time_Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08/22/2010 24 hr Summary Mobilze rig from 3K pad to 3N pad. Excemptional Rig move. 12:00 00:00 12.00 MIRU MOVE MOB P Move to 3N-16 08/23/2010 Swapped skates on injector, Began BOP test. State wavied witness by Chuck Schvick.Accepted Rig @ Midnight. 00:00 16:00 16.00 MIRU MOVE RGRP T Rig spotted over well and BOP's flanged up Work on installing new style Injector Skates Nabors on non-billable time for Injector Skate repair 16:00 20:30 4.50 MIRU WHDBO SVRG P ****Rig Accept at 1600 hrs on 8/23/10***** Prepare for BOP test,grease choke valves 20:30 00:00 3.50 MIRU WHDBO BOPE P BOP Testing LOW 250 psi High p 3500psi. n �` 08/24/2010 (47 Complete BOP test. (All Pass)Pumped Slack-cut 15 ft to find cable.Cut 700'off CT string. RIH with Dummy WS&Circ well over to milling fluid. 00:00 05:00 5.00 0 0 MIRU WHDBO BOPE P Continue BOP test. Low 250 High 3500psi.The only failure was lower swab valve.Greased&passed. 05:00 06:00 1.00 0 0 SURPRI WELLPF SLPC P Reverse circulate for slack management 06:00 06:30 0.50 0 0 SURPRI WELLPF SFTY P Crew change PJSM 06:30 07:00 0.50 0 0 SURPRI WELLPF SLPC P RU to cut CT 07:00 08:30 1.50 0 0 SURPRI WELLPF SLPC P Cut CT,700'-Found cable 15 ft into cutting pipe. 08:30 09:00 0.50 0 0 SURPRI WELLPF SLPC P RD cutter, Prepare to pull BPV 09:00 09:30 0.50 0 0 SURPRI WELLPF SLPC T E-line not testing, Diagnose.-bad cut on cable-cut addional 5ft and test. 09:30 10:00 0.50 0 0 SURPRI WELLPF MPSP P Eline Tested. RU to pull BPV 10:00 11:30 1.50 0 0 SURPRI WELLPF MPSP P Pull BPV 11:30 13:00 1.50 0 0 SURPRI WELLPF SLPC P Install CTC, Pull test 35K. BHI head up drilling head 13:00 13:30 0.50 0 0 SURPRI WELLPF SLPC P PSI test CTC,4200psi,Stab onto well, PT backside Tiger tank line. 13:30 13:45 0.25 0 0 PROD1 RPEQP1SFTY P PJSM,MU BHA 13:45 15:15 1.50 0 71 PROD1 RPEQPI PULD P MU BHA#1 �_ Page 1 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 18:15 3.00 71 8,190 PROD1 RPEQP1TRIP P RIH pumping SW&flushing diesel from well to TT. SSSV open. No BHP.Tie in @ 7700'with-6 ft correction. RIH down to 8190'-clean drift.-Clean SW to surface. 18:15 20:45 2.50 8,190 71 PROD1 RPEQP1TRIP P POOH pumping milling fluid. 20:45 21:15 0.50 71 0 PROD1 RPEQP1PULD P lay down Dummy WS 21:15 22:15 1.00 0 0 PROD1 RPEQP1SFTY P Pre-spud meeting with crew 22:15 23:15 1.00 0 71 PROD1 RPEQP1PULD P P/U WS assembly with EDC open. 23:15 00:00 0.75 71 2,500 PROD1 RPEQP1TRIP P RIH pumping 0.3 bpm through EDC. 08/25/2010 Set TOWS @ 8170'-P/U Milling BHA-BHI software problems(counter)-Start milling window from 8165'to 8170'-Continue milling formation to 8181'.Three reaming passing and clean dry run through window. POOH 00:00 01:30 1.50 2,500 7,800 PROD1 !RPEQP1TRIP P RIH-pumping 0.3 bpm through EDC. Tie in with-10.3 ft correction. 01:30 02:00 0.50 7,800 8,179 PROD1 RPEQP1WPST P RIH weight check @ 8100'-28K. RIH slowly through landing collar. Turn 10 degree ROHS>-RIH to setting depth of 8178.5. Close EDC. **TOWS 8170'*** 02:00 03:30 1.50 8,179 71 PROD1 RPEQP1TRIP P TOWS 8170'-Pressured up to 4250 psi, Setting indication,WOB 6K, P/U weight 29K. POOH-pumping @ 0.8 bpm. 03:30 04:30 1.00 0 PROD1 RPEQPI PULD P Flo-check-lay down BHA.Setting assembly looked good at surface. 04:30 05:30 1.00 71 72 PROD1 WHPST PULD P P/U milling BHA.Serviced injector and top drive. 05:30 07:15 1.75 72 7,790 PROD1 WHPST TRIP P RIH with 2.80 mill&2.79 String mill on 0.6 deg motor 07:15 07:30 0.25 7,790 8,168 PROD1 WHPST DLOG P Tie in depth,-11.5'correction, RIH 07:30 09:00 1.50 8,168 8,165 PROD1 WHPST EQRP T Dry tag TOWS. PUH BHI counters not working. PUH 26K slowly, Diagnose problem 09:00 10:30 1.50 8,165 8,166 PROD1 WHPST MILL P Online with pumps.Start milling. 3000 CTP, 341 diff,Try to get started, BHI counters wokring now. Stalled 6X trying to get started 10:30 17:30 7.00 8,166 8,170 PROD1 WHPST MILL P Start milling 1 FPH auto driller, .5-2.5K WOB, 1.4 BPM, in and out, 9K CTW,400 Diff 17:30 20:30 3.00 8,170 8,181 PROD1 WHPST MILL P Exit out window-continue milling as per procedure. Metal shavings, Cement and 2%formation in sample. IA 780-OA 380.Sample @ 8178'- 6%solids.WOB 1.4K, 3-4 fph. 20:30 21:30 1.00 8,181 8,181 PROD1 WHPST REAM P Make 3 backreaming passes 10 degree HS from 8173-8162'. 1 fpm, 1.40 bpm, circ 2700psi,slight motor work @ 8167'first pass. 18% formation in samples with traces of cement. Page 2 of 23 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 8,181 8,181 PROD1 WHPST DLOG P Down on pumps-perform dry run @ 10 fpm.Clean. P/U and tie in RIH @ 7790'.Zero correction. RIH dry drift down to 8181.8'. 22:00 23:30 1.50 8,181 69 PROD1 WHPST TRIP P POOH to P/U build assembly. 23:30 00:00 0.50 69 0 PROD1 WHPST PULD P Flo-check&lay down BHA.-2.80" go 2.79"no-go 08/26/2010 RIH with build assembly,clean drift through window. Drill build section to 8345'.Tie into RA marker-correct Window depths:TOW 8170'-RA marker 8174'BOW 8175'. 00:00 01:30 1.50 0 62 PROD1 DRILL PULD P Lay down Milling BHA&P/U Build BHA. Harder time working 2.5 AKO through BOP stack. 01:30 03:30 2.00 62 7,900 PROD1 DRILL TRIP P RIH slowly through restrictions-set up for mud swap. 03:30 04:00 0.50 7,900 8,185 PROD1 DRILL TRIP P Tie in-6ft correction.(yesterday was -11) P/U weight 27K RIH slowly through window.Clean drift tag bottom @ 8185'. 04:00 06:00 2.00 8,185 8,212 PROD1 DRILL DRLG P Start drilling ahead with new Flo-pro. 06:00 08:30 2.50 8,212 8,260 PROD1 DRILL DRLG P Drill Ahead 5-30 FPH 1.4 BPM in/out,3000 circ psi,OWHP,6K RIW,3K WOB,200-250 motor work 08:30 08:45 0.25 8,260 8,260 PROD1 DRILL WPRT P Wiper trip to window 27K PUW. PUH through window tieing into Cased hole tie in marker,0 correction 08:45 09:00 0.25 8,260 8,260 PROD1 DRILL DLOG P Tie into RA marker, PU RA marker at 8174'. TOWS=8170' RA marker=8174' BOW=8175 09:00 10:45 1.75 8,260 8,281 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM in/out,25-30 FPH,3000 CTP,8-9K CTW,3655 BHP, 150-200 Motor work 10:45 15:15 4.50 8,281 8,300 PROD1 DRILL DRLG P Slow drilling on ankerite 5 FPH 2-2.5K WOB 15:15 16:15 1.00 8,300 8,345 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm in/out,5-7K CTW,3350 CTP,2K WOB,40-50 FPH 16:15 18:15 2.00 8,345 68 PROD1 DRILL TRIP P Land build section, POOH 26K PUW Open EDC in cased hole. POOH 18:15 20:15 2.00 0 71 PROD1 DRILL PULD P Lay down Build BHA, P/U drilling BHA with rebuild razor bi-center& 1.1 AKO. 20:15 22:30 2.25 71 8,345 PROD1 DRILL TRIP P RIH-tie in-6ft. Clean drift through window&build section. 22:30 00:00 1.50 8,345 8,435 PROD1 DRILL DRLG P Drilling ahead-1.42 bpm,3200psi, BHP 3676, ECD 10.9, ROP 80, WOB 2K,Ct weight 6K.good returns. 08/27/2010 Drilled ahead in All lateral. Poor shale section from 8700 to 8740'. 118 bbls losses in 24 hours. 00:00 00:45 0.75 8,435 8,495 PROD1 DRILL DRLG P Continue drilling ahead 00:45 01:45 1.00 8,495 8,495 PROD1 DRILL WPRT P P/u weight 26K Wiper trip with MADD PASS Page 3 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:45 02:45 1.00 8,495 8,550 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3100 psi, BHP 3697, ECD 11, ROP 50,WOB 1.4K,CT weight 6K. 02:45 03:45 1.00 8,550 8,645 PROD1 DRILL DRLG P Started to get losses-1.45 bpm in 1.15 bpm out.circ 3300psi, BHP 3671, ECD 10.9, ROP 90,WOB 2K, Ct weight 7K.drilling ahead. 14 bbl losses last hour. 03:45 04:30 0.75 8,645 8,645 PROD1 DRILL WPRT P Wiper trip-P/U weight 25K. Fluid losses getting better. 1.45 in-1.25 out. 04:30 06:00 1.50 8,645 8,734 PROD1 DRILL DRLG P Continue drilling ahead-1.43 bpm, 1.30 bpm returns,3400 psi, BHP 3700, ECD 11, ROP 60,WOB 2K, Ct weight 6K 06:00 07:00 1.00 8,734 8,795 PROD1 DRILL DRLG P Drill ahead 1.4 BPM in, 1.2 BPM out, 3350 CTP,6K CTW,2.4 WOB,3700 BHP 07:00 07:30 0.50 8,795 8,795 PROD1 DRILL WPRT P 8770'Stall, possible fault. Wiper trip back to window,26K PUW, 07:30 08:15 0.75 8,795 8,795 PROD1 DRILL WPRT P Tie in depth to RA marker,0 correction, RIH 08:15 10:15 2.00 8,795 8,945 PROD1 DRILL DRLG P Drill ahead 1.4 BPM in, 1.1 BPM out, 3250 CTP,6K CTW, 1-2K WOB, 3700 BHP 10:15 11:00 0.75 8,945 8,945 PROD1 DRILL WPRT P Wiper trip to window,25K PUW 11:00 13:45 2.75 8,945 9,095 PROD1 DRILL DRLG P Drill Ahead 50-70 FPH, 1.4 in, 1.2 BPM out, 1.5-2K WOB,5-6K CTW, 3200 CTP 13:45 14:45 1.00 9,095 9,095 PROD1 DRILL WPRT P Wiper Trip to window,26K PUW Stack out 8700-8740'.Get through shale minimum rate 14:45 17:15 2.50 9,095 9,245 PROD1 DRILL DRLG P Drill Ahead 50-70 FPH, 1.4 in, 1.2 BPM out, 1.5-2K WOB,5-6K CTW, 3200 CTP 17:15 18:45 1.50 9,245 9,245 PROD1 DRILL WPRT P Wiper tirp to window-tie in with zero correction. Slow pump rates through shale area. 18:45 21:15 2.50 9,245 9,395 PROD1 DRILL DRLG P Drilling ahead-1.44 bpm in, 1.45 out,3400 psi, BHP 3733, ECD 11.2, ROP 50,WOB 1.72K,Ct weight 6K. 21:15 22:45 1.50 9,395 9,395 PROD1 DRILL WPRT P Wiper trip-P/U weight 27K. 22:45 00:00 1.25 9,395 9,466 PROD1 DRILL DRLG P Drilling ahead- 5 bbl lost per hour. 08/28/2010 TD lateral to 9755'-pump liner pill. Had two overpulls inside casing @ 7700'. RIH&circ B/U with heavy shale returns to surface. P/U Liner assembly and hard tag @ 8277'Ankerite area. POOH. 00:00 01:00 1.00 9,466 9,545 PROD1 DRILL DRLG P Continue drilling ahead-1.45 bpm, 3300psi, BHP 3780, ECD 11.3, ROP 50,WOB 1.7K,CT weight 5.5K. 01:00 03:00 2.00 9,545 9,545 PROD1 DRILL WPRT P Wiper trip 27K P/U 03:00 05:00 2.00 9,545 9,672 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3300 psi, BHP 3770, ECD 11.2, ROP 55, WOB 1.4K, Ct weight 6K Page 4 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 05:15 0.25 9,672 9,672 PROD1 DRILL DRLG P Two stalls on bottom drilling. P/U weight 30K off stall.Started stacking surface weight while RIH-pull wiper early by 20'. 05:15 07:00 1.75 9,672 9,672 PROD1 DRILL WPRT P Wiper trip-P/U weight 29K 07:00 08:30 1.50 9,672 9,755 PROD1 DRILL DRLG P Drill Ahead ' 08:30 09:45 1.25 9,755 9,755 PROD1 DRILL WPRT P TD lateral at 9755'; Wiper trip to window,26K PUW 1/` 09:45 10:00 0.25 9,755 9,755 PROD1 DRILL OWFF P PUH through window to perform static test.2885 psi BHP at window (8.7 ppg EMW)and dropping 10:00 11:00 1.00 9,755 9,755 PROD1 DRILL WPRT P RIH to TD 11:00 12:00 1.00 9,755 9,755 PROD1 DRILL DISP P POOH laving in beads, 45 fpm, 0.42 bpm, beads out at 7875'. 12:00 13:00 1.00 9,755 9,755 PROD1 DRILL WPRT T Pulled heavy 18k over in cased hole @ 7625 and 7650. Increase pump rate to 1.4 bpm, rbih to window, down on pump,drift through window, no problems. 13:00 15:00 2.00 1,172 PROD1 DRILL TRIP P Pooh pumping 1.4 bpm. 15:00 15:15 0.25 9,755 0 PROD1 DRILL SFTY P @ surface,conduct safety meeting. Monitor well for flow 15:15 16:00 0.75 0 0 PROD1 DRILL PULD P lay down BHA#5, 16:00 16:15 0.25 0 0 COMPZ CASING PUTB P Prep floor for running liner. 16:15 16:30 0.25 0 0 COMPZ CASING SFTY P PJSM 16:30 18:15 1.75 0 1,100 COMPZ CASING PUTB P pU/MU liner on BHA#6 18:15 19:15 1.00 1,100 1,175 COMPZ CASING SFTY P Safety joint drill following hand-over. Pass-P/U Gs profile and finish running liner BHA. 19:15 21:00 1.75 1,175 8,277 COMPZ CASING RUNL P RIH pumping.3 bpm-EDC closed. Flag-4 ft correction.Weight check- 29K.smooth through window. RIH 50 fpm.Tagged up 8277'-P/U weight 30K. 21:00 22:00 1.00 8,277 8,277 COMPZ CASING RUNL T Sat down 8274'.Ankerite area in build section. 10 short attempts, P/U to 8200'and make longer attempts. Trap 600 psi on WH while pumping to try again. No luck-total of 20 attempts. 22:00 23:30 1.50 8,277 1,172 COMPZ CASING TRIP T POOH-paint flag EOP-6900', Open EDC&follow MPD while POOH. 23:30 00:00 0.50 1,172 1,172 COMPZ CASING OWFF T CT @ surface,trapped 800 psi on WH, Shut SSSV-bleed off WH pressure and monitor well for 15 minutes. Slight trickle for 5 minutes then flow-stopped-no-flow. Lay down BHA 08/29/2010 Lay down Liner, P/U clean out assembly with D331 bit.Troubled spots 8216',8787'-heavy marble shales over shakers.Continue cleaning well, lots of cutting coming over shakers all 3 wiper trips. Final wiper-lost full returns, Lay in Liner pill-WH pressure came back at window. Hold MPD While POOH.*140 bbls losses in 24 hours** Page 5 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 1,172 0 COMPZ CASING PULL T Lay down liner.Guide shoe completly packed off with Shale marbles. 02:00 04:00 2.00 0 0 COMPZ CASING PULD T Make up BHA#7 with a 1.0 AKO motor with smooth OD D331 bit. 04:00 06:00 2.00 62 8,272 COMPZ CASING TRIP T RIH with cleanout assembly following MPD schedule. 06:00 06:30 0.50 8,272 8,100 COMPZ CASING FCO T Tagged at 8216, puh to 8100, rbih pumping 1.4 bpm. 06:30 07:00 0.50 8,100 8,200 COMPZ CASING FCO T Motor work at 8218, rih to 8244,puh to window. 07:00 07:30 0.50 8,244 8,244 COMPZ CASING FCO T Rbih to 8244,end of motor work, puh, pu wt is 25k. 07:30 08:00 0.50 8,244 8,350 COMPZ CASING FCO T RIH cleaning hole to 8350,puh to 8200,pu wt is 26k. 08:00 09:00 1.00 8,350 8,550 COMPZ CASING FCO T Rih to 8550, puh to 8200, pu wt is 26k. 09:00 10:00 1.00 8,550 8,787 COMPZ CASING FCO T Stack out at 8787,puh, heavy wt swings to 43k until 8675, increase WHP to 150 psi,puh to 8580, 10:00 11:00 1.00 8,580 8,705 COMPZ CASING FCO T Rih pumping 10 bbl sweep,continue milling through shales. 11:00 14:30 3.50 8,705 8,726 COMPZ CASING FCO T Swap mud out,continue milling down 14:30 14:42 0.20 8,754 8,780 COMPZ CASING FCO T @ 8754, puh,try making runs in, able to work through, rih at 35 fpm., Large amounts of cuttings across shakers 14:42 15:42 1.00 8,780 9,755 COMPZ CASING FCO T Continue PUH to 8650, RIH making hole. 30-35K PUW,-10 to 10K RIW. RIH 35 FPM,Continue getting large amounts of cuttings across shakers 15:42 16:42 1.00 9,755 9,755 COMPZ CASING FCO T Tag 9755 TD,Wipe back to window, Looked good. Still large amounts of cuttings across shakers,drift through shales good. 16:42 17:42 1.00 9,755 9,755 COMPZ CASING FCO T RIH,tag 8216'PUH,28K, RIH,To TD. Drift through shales no problems. RIH to TD. 17:42 19:42 2.00 9,755 7,100 COMPZ CASING FCO T Wiper trip-P/U weight 25K. Came up to 7100'returns are a lot cleaner, light silty cutting over shaker-RIH to TD 19:42 20:42 1.00 7,100 9,755 COMPZ CASING FCO T RIH,pumping 1.2 bpm, 11.4 ECD, build looked clean,8703'slight weight stacking,did not adjust rates and slid through pretty clean. 20:42 21:42 1.00 9,755 8,000 COMPZ CASING FCO T P/U off bottom 26K,clean hole.Wipe up slowly while setting up to pump sweep when hole pressures dropped off while wiping up, returns dropped off. 1.5 bpm in,0.3 bpm out. ECD dropped to 10.2. Lost all returns. POOH up to cased hole. Still min. returns 0.2 bpm. Clean weight POOH. Page 6 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:42 23:12 1.50 8,000 9,755 COMPZ CASING FCO T RIH to spot liner pill,followed by used mud from Pit#7. Zero to 0.2 bbl returns to surface.Try to trap pressure on well with no luck. 23:12 00:00 0.80 9,755 8,000 COMPZ CASING TRIP T POOh laying in liner pill 0.4bpm/40 fpm.Slight overpull @ 8700'- continue POOH.Started getting positive WH pressure @ 8300'. Continue to hold MPD while POOH- _ clean through build&window. 08/30/2010 P/U Liner assembly with 1.5 Degree bent sub, RIH to TD. Liner set 9755'-8622', RIH with Anchored Billet from 8622'-TOB 8611'. POOH, weekly function test of BOP's.22 bbls loss for 24 hours. 00:00 02:00 2.00 8,000 61 COMPZ CASING TRIP T POOH following MPD,slight losses occuring.Clean returns to surface. 02:00 02:30 0.50 61 61 COMPZ CASING PRTS T Shut in SSSV trapped 800 psi- SSSV leaking by on no-flo. Pump& Pressure up 1000psi,bleed&shut same time-Held-no flo for 15 minutes 02:30 03:00 0.50 0 0 COMPZ CASING PULD T lay down BHA#7. 03:00 05:30 2.50 0 0 COMPZ CASING PUTB T Prep,safety meeting&start P/U BHA#8. Liner with 1.5 degree sub and bull nose. 05:30 07:30 2.00 0 0 COMPZ CASING RUNL T PSI up well 850 psi above SSSV. Open SSSV, Bleed down to 350, RIH. 07:30 08:15 0.75 0 8,100 COMPZ CASING RUNL P RIH, PU wt at 8100 is 28k, rih. 08:15 08:45 0.50 8,100 9,397 COMPZ CASING RUNL P Tagged at 9397, pu wt is 35k. Single pick up and slip past. 08:45 09:15 0.50 9,397 9,762 COMPZ CASING RUNL P RIH to TD,try to release off liner with 3000 psi,30-35K PUW, liner not released, increase to 4000 psi,26K PUW, liner released, POOH 09:15 09:45 0.50 9,762 7,783 COMPZ CASING DLOG P Tie in depth at 7783,6'correction, liner on bottom 9755'. 09:45 11:30 1.75 7,783 0 COMPZ CASING TRIP P POOH. 11:30 12:00 0.50 0 0 COMPZ CASING SFTY P At surface, PJSM 12:00 14:30 2.50 0 0 COMPZ CASING PULD P Undeploy, LD BHA#8 14:30 15:30 1.00 0 73 PROD2 STK PULD P PU BHA#9 15:30 18:30 3.00 73 8,622 PROD2 STK TRIP P RIH with OH Anchor and Aluminum billit.Tie-7ft correction. Close EDC, P/U 29K.Clean through window& build. 18:30 19:00 0.50 8,622 8,611 PROD2 STK ANCR P TOB-@ 8611'-Set down 5K. P/U string weight 28K&pump online- pressure up to 4700 psi-good set indication-P/U weight 26K,Circ pressure 2400 psi pumping 0.8 bpm with 300 WHP. Orient TF 1OR coming through window. 19:00 21:00 2.00 8,611 69 PROD2 STK TRIP P Clean though window-POOH following MPD Page 7 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 69 0 PROD2 STK PULD P CT @ surface-Undeploy BHA, break down BHA-setting tool looked good. 23:00 23:30 0.50 0 0 PROD2 STK BOPE P Weekly function test of the BOP system. Inspect pump HP filter screens. 23:30 00:00 0.50 0 0 PROD2 STK SLPC P Inspect CT connector and cut coil due to pipe damage-total of 15 ft cut. 08/31/2010 Cut 25 coil and rehead. M/U Drill by BHA and drill past Billet @ 8609. Drill ahead to 8990.24 Hr Fluid loss 76 BBIs 00:00 02:00 2.00 0 0 PROD2 STK SLPC P Re-head CT connector. Holding 900 psi on MPD. Pressure&pull test connector. 02:00 04:30 2.50 0 0 PROD2 STK PULD P Make up drilling BHA-Start deploying 04:30 06:06 1.60 0 7,783 PROD2 STK TRIP P RIH 06:06 06:21 0.25 7,783 7,783 PROD2 STK DLOG P Tie in depth,-7'correction 06:21 06:36 0.25 7,783 8,610 PROD2 STK TRIP P RIH,dry tap billet 8610.17 06:36 09:36 3.00 8,610 8,610 PROD2 STK KOST P Start milling ST,Stall X 2,getting O, started,Trough above ST, possible `' slip sticking. 1'FPH for 1' ej 2 FPH for 1' C 3 FPH for 1' 10 FPH for 5' 20 FPH for 2' 09:36 11:36 2.00 8,610 8,613 PROD2 STK KOST P Still getting stalls-@ 8610'.3.Wiper up 70'add 50 psi to choke pressure. 1.40 bpm,3000psi, BHP 3830, ECD 11.4, ROP 1,WOB.3K,Ct weight 9K. No more stalls after choke pressure&wiper-70%formation- 30%Al. in returns. @ 8611.5'. Increase to 3 fpm. 11:36 12:36 1.00 8,613 8,640 PROD2 STK KOST P 90%formation in samples, Increase to 15 ft hour for 7 ft then start increasing WOB and drilling ahead 25 ft. Drift through billet-clean up/down no pumps. 12:36 13:36 1.00 8,640 8,640 PROD2 DRILL WPST P Wiper trip to window prior to drilling lateral.Tie in-1 ft correction.Clean wiper&drift.TOB 8609'-8612' 13:36 16:36 3.00 8,640 8,790 PROD2 DRILL DRLG P Drilling ahead-Started fluid losses @ 8650'-1.40 bpm in.6 bpm out. Holding 80 psi on choke seems to help. rates-1.40 bpm out 1.2 bpm, 3500 psi, BHP 3850, ECD 11.3, ROP 60,WOB 2.2K,WHP 60 psi. 16:36 17:24 0.80 8,790 8,790 PROD2 DRILL WPRT P Wiper trip to 8260-P/U weight 29K. 17:24 21:00 3.60 8,790 8,916 PROD2 DRILL DRLG P 8790', Drill ahead 1.41 BPM @ 3140 PSI FS BHP=3898 WOB=2.2K Slow ROPs since 8700'(Fault) Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:24 0.40 8,916 8,940 PROD2 DRILL DRLG P 8916, Drilling break. ROP 60 to 80 FPM Still ratty drilling 21:24 22:15 0.85 8,940 8,940 PROD2 DRILL WPRT P 8940,Wiper to 8620, PUW=30k Clean wiper in and out. Lost 7 BBIs on trip 22:15 23:00 0.75 8,940 8,970 PROD2 DRILL DRLG P 8940', Drill Ahead 1.39 BPM @ 3200 FS BHP=3765 23:00 23:45 0.75 8,970 8,970 PROD2 DRILL WPRT P 8970', Pull off bottom to discuss anti collision options. 23:45 00:00 0.25 8,970 8,980 PROD2 DRILL DRLG P Drill ahead 1.4 BPM @ 3200PSI FS, BHP=3800 Midnight depth 8980 09/01/2010 Drill to 9240', unable to get past 8250 on wiper from 9240. POOH to get clean out BHA.Get past 8250 but not 8480. POOH to decrease AKO setting. Lost 657 BBIs last 24HRs 00:00 02:00 2.00 8,980 9,090 PROD2 DRILL DRLG P Drilling ahead 02:00 04:00 2.00 9,090 8,198 PROD2 DRILL WPRT P Wiper trip to 7100. Pump lo hi vis sweep PUW=27K BHP=3790 04:00 04:06 0.10 8,198 8,216 PROD2 DRILL DLOG P Tie in to RA Marker on whipstock for no correction 04:06 04:45 0.65 8,216 9,090 PROD2 DRILL WPRT P Continue in well on wiper trip. Set down @ 8834, Pulled heavy after pick up 36K. 80L orientation Stop @ 8850 and ream up at as drilled. No overpull. Lost Returns BHP down to 3564 04:45 06:30 1.75 9,090 9,150 PROD2 DRILL DRLG P 9090', Drill ahead 1.3 BPM @ 2800PSI No Returns BHP=3480 06:30 07:30 1.00 9,150 9,240 PROD2 DRILL DRLG P Do a quick P/U 29K weight. Drill ahead-shut in choke to try and build up BHP.Took 30 minutes before positive indication on choke 60 psi. No returns. BHP increased 30 psi to 3460 psi. 07:30 08:30 1.00 9,240 8,140 PROD2 DRILL WPRT P Wiper trip-39K P/U weight-choke @ 90 psi with a trickle of returns. Increase choke to 200 psi-BHP increase slowly to 3500 psi during wiper.Clean up through build& window. 08:30 09:30 1.00 8,140 7,100 PROD2 DRILL CIRC P Open EDC&POOh to 7000'-try to get returns. Returns started @ 7800' -full returns @ 7400'. Pump B/U before RIH. BHP 3560psi @ 7500'. Cutting over shakers. BHP fell out again near B/U. �r 09:30 10:30 1.00 7,100 8,250 PROD2 DRILL TRIP P ,RIH-close EDC-tie in,tagged Ca? 8250'.Clean P/U.tried 6 times diffent TF 10 R,80 L, HS. Shut in choke try build pressure&no luck tagging _up higher. Page 9 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:30 13:00 2.50 8,250 71 PROD2 DRILL TRIP T Call town-POOH-Open EDC-try to keep MPD while POOH. 13:00 15:00 2.00 71 0 PROD2 DRILL PULD T On surface, PJSM. un-deploy BHA to change out mill. Injecting roughly 10 bbls per hour at surface with 700 psi on WHP. New skates are causing gripper blocks to slightly grab the pipe when stripping procedure is taking place. Inspect CT. 15:00 17:00 2.00 0 0 PROD2 DRILL SVRG T Make up new BHA-clean and inspect injector head. Injecting 10 bbl/hour holding MPD @ 700 psi. 17:00 18:45 1.75 0 0 PROD2 DRILL PULD T Begin deploying, BHA#11. 2 Degree motor and 2.79 smooth OD D331 Mill. Surface test good 18:45 20:15 1.50 0 62 PROD2 DRILL TRIP T RIH with cleanout BHA. EDC Open. Trying to keep as much pressure on formation as possible 20:15 20:45 0.50 62 7,825 PROD2 DRILL DLOG T 7785, Log gamma tie in,-15' correction BHI had computer issues running in hole 20:45 21:15 0.50 7,825 8,250 PROD2 DRILL TRIP T Close EDC and trip in well 21:15 21:30 0.25 8,250 8,300 PROD2 DRILL FCO T Run into 8250. Saw little on DH WOB. 1.4BPM @ 2590 FS. Returns 0.1 to 0.6 then full returns on way to window. Pull up to 8200 looks good 21:30 21:45 0.25 8,300 8,300 PROD2 DRILL FCO T Run into 8300 clean. Returns went down to.3 to.5. PUW=29k going back to window. Pump 10 BBI Hi Vis Sweep 21:45 22:45 1.00 8,480 8,260 PROD2 DRILL FCO T 8480, Set down and get full returns, 1.42 in/1.34 out. High vis sweep coming out. Going to chase to window and circ bottoms up to clean up what hole we have. 22:45 22:51 0.10 8,260 8,480 PROD2 DRILL FCO T 8260'Got bottoms up. Not much across shaker RBIH to work 8480 area 22:51 23:45 0.90 8,480 8,480 PROD2 DRILL FCO T 8480',try multiple speeds, pump rates,WH Pressures and tool faces. Getting full returns. and BHP=3726. Trip out for a 1.3 degree motor 23:45 00:00 0.25 8,480 8,300 PROD2 DRILL TRIP T Trip out for less bend on motor following MP schedule 09/02/2010 POOH to dial down motor AKO from 2 to 1.3. Clean out to 8720.Trip for Bi Center to get past 8720 00:00 01:45 1.75 8,300 0 PROD2 DRILL TRIP T Continue out of well to dial down motor angle 01:45 04:45 3.00 0 62 PROD2 DRILL PULD T At surface, PJSM. Undeploy BHA #11 and Pick Up BHA#12 for FCO with 1.3 degree motor and D331 Mill. Surface Test tool Page 10 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 06:45 2.00 62 8,487 PROD2 DRILL TRIP T Trip in Well,clean drift through window and P/U pump rate in lateral. Good 1:1 returns. Continue RIH. Weight check 26K. 06:45 09:15 2.50 8,487 8,595 PROD2 DRILL FCO T Started getting motor work,start cleaning hole. Losing returns @ 8525'. BHP 3750 psi.Silty&claylike returns over shakers.Alum&metal shavings mixed in.Slow drilling down to 8580' 09:15 10:00 0.75 8,595 8,575 PROD2 DRILL WPRT T Slowly moving forward down to 8598' P/U for wiper prior to billet-@ 8578' -rolled BHA over and got bit stuck. Motor stall try moving pipe no luck. Zero returns to surface. Up 8575'P/U weight 40K 4K on BHA Down 8583'-zero weight+6K on BHA 10:00 10:30 0.50 8,575 8,575 PROD2 DRILL WPRT T Worked free max. pull 48K with 7K on bit.Started getting returns when worked free.Wipe to window,work back down to troubled spot @ 8573'. Lost returns @ 8575'. 10:30 11:30 1.00 8,575 8,602 PROD2 DRILL FCO T Start milling on formation @ 8570' Motor work detected.Work through troubled spot to 8602'-mostly sand in returns.Wipe up to window prior to RIH through billet.Clean P/U 27K. 75%returns. 11:30 13:15 1.75 8,602 8,620 PROD2 DRILL FCO T Try RIH dry through billet-bridged off.Continue cleaning lowside near billet. FCO past Billet down to 8620' P/U due to stacking while milling. Sand in returns,very light shale.27K weight.60%fluid returns. 13:15 15:15 2.00 8,620 8,720 PROD2 DRILL FCO T Continue working down,worked numerous times around billet area, 80%returns. Hard cleaning from 8680-8720'. 15:15 16:00 0.75 8,720 8,730 PROD2 DRILL FCO T Wiper trip to window-clean up lateral and improve losses. P/U weight 28K. Continue cleaning,very little prgress -decision to POOH. 16:00 18:15 2.25 8,730 0 PROD2 DRILL TRIP T Trip out of well for Bi Center bit 18:15 21:45 3.50 0 0 PROD2 DRILL PULD T On Surface PJSM to swap out BHA #12 for#13 Bi Center bit and resistivity 21:45 23:30 1.75 0 7,805 PROD2 DRILL TRIP T Trip in well with BHA#13. 1.3 degree motor, Bi Center and resistivity 23:30 23:45 0.25 7,805 7,831 PROD2 DRILL DLOG T Log Gamma tie in for a-6.5' correction Close EDC, PUW=28k 23:45 00:00 0.25 7,831 8,670 PROD2 DRILL TRIP T Continue in well Midnight Depth 8670 tripping in 09/03/2010 POOH drop Bi Center and P/U mill for clean out. Page 11 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:36 0.60 8,670 8,732 PROD2 DRILL FCO T Tag @ 8711 hard tag @ 8732. PUW=40 Dragging uphole drag 34K 1.3 BPM @ 2450 FS Pump LoHi Sweep 8700 still dragging heavy 00:36 02:24 1.80 8,732 8,200 PROD2 DRILL FCO T RBIH from 8618 to 8732. returns coming and going. Multiple setdowns. Mini wipers up. Poor hole conditions,working most areas.wipe back up to 8200 02:24 02:54 0.50 8,200 8,732 PROD2 DRILL FCO T RBIH to bottom. Hard setdown @ 8335 wipe up 50'. RIH a little faster and go through. Bring pumps up to 1.4 and setdown @8351. Made it down to 8732 with pumps on. 02:54 03:09 0.25 8,732 8,732 PROD2 DRILL FCO T Set down at 8732 low motor work with 4K WOB. Motor work went away and WOB stayed constant. Would say we were packing off around BHA but had returns. BHA wiper, pump LoHi vis sweep 03:09 04:09 1.00 8,732 8,714 PROD2 DRILL FCO T 8738 stalled 3 times.sticky pickups returns coming and going. Dragging heavy continue to work pipe. Wipe up to Billit with sweeps then _ RBIH 04:09 04:57 0.80 8,714 8,810 PROD2 DRILL FCO T Ream down taking bites at as-drilled TF. 1.3 BPM Holding 200 LBS WHP is helping BHA wipers as required, PUW 29 to 32K 04:57 06:57 2.00 8,810 8,220 PROD2 DRILL FCO T Pick ups getting sticky wipe to billit @8690 PUW=30k, RIH tagged @ 8700' Overpull-slight bit stuck.Wipe to window. 06:57 07:27 0.50 8,220 8,125 PROD2 DRILL CIRC T 8220'area having problems again. 12 attempts to get through area. Good 1:1 returns, BHP jug tight. POOH above window-try to establish injection rate.Open EDC .5 bpm= 3780 BHP/WHP 500/ rate out.3 1 bpm=3840 BHP/WHP 450/rate out.8 1.2 bpm=3890/WHP 450/rate out 1 bpm 07:27 10:12 2.75 8,125 8,222 PROD2 DRILL TRIP T Close EDC-try RIH made 2ft down to 8222'POOH following MPD to change BHA to D331 with 1.5 AKO. 10:12 11:27 1.25 8,222 61 PROD2 DRILL PULD T Undeploy BHA-trying to hold MPD- injecting 30 bbls/hour @ 600psi. 11:27 12:27 1.00 71 0 PROD2 DRILL SFTY T Swabs shut.Safety meeting with both crews-crew change. Page 12 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:27 14:27 2.00 0 62 PROD2 DRILL PULD T Deploy BHA#14 with 1.5 AKO& D331 Mill for FCO. Injected roughly 55 to 60 bbls at surface. 14:27 16:27 2.00 62 8,220 PROD2 DRILL TRIP T RIH following MPD.Tie in-7, P/U weight 29K.Close EDC, RIH to 8220' Start seeing Weight bobbles. P/U for weight check-27K 16:27 17:27 1.00 8,220 8,407 PROD2 DRILL FCO T 1.40 bpm, BHP 3770,WHP 150, rate out 1.2 bpm. RIH 10 fpm, light motor work detected off/on. Returns to surface starting to drop off around 8290'. P/U weight 29K. hard tag @ 8300' 17:27 21:12 3.75 8,407 8,700 PROD2 DRILL FCO T 8300-start Milling 1.40 bpm, 3000psi, BHP 3700, ECD 11.1 Continue to work pipe and wipe hole to get to 8700 Pump loHi vis sweeps 21:12 22:27 1.25 8,700 7,100 PROD2 DRILL FCO T 8700',at TD,pump lohi sweep,Wipe hole up to 7100'. PUW=25K 22:27 23:42 1.25 7,100 7,795 PROD2 DRILL FCO T At 7100', RBIH to tie in 23:42 00:00 0.30 7,795 7,816 PROD2 DRILL DLOG T 7795, Log gamma tie in correct+2 trip in to bottom 09/04/2010 Completed FCO to 8700. POOH,M/U and run liner to 8683,TOL 8167 00:00 01:30 1.50 7,816 8,700 PROD2 DRILL FCO T Run through window clean.Work pipe down to 8700. Bad area from 8229 to 8325. Better conditions below Billet @ 8609'Trying to maintain 11.2 ECD 01:30 03:00 1.50 8,700 8,200 PROD2 DRILL FCO T 8700', PUH to 8200.Multiple set downs on way back 8228 and set down @ 8330 and having problems getting down below 8330 03:00 03:30 0.50 8,200 8,330 PROD2 DRILL FCO T Wipe up to 8265 then back down still not able to get past 8330'. Clean pickups off this depth PUW=29k ECD=11.17 03:30 03:48 0.30 8,330 8,350 PROD2 DRILL FCO T 8328,Still unable to pass.Going to have to mill here 1.45 BPM. .5 BPM returns, BHP=3630, ECD=11.17,WHP=150 PSI 03:48 03:54 0.10 8,350 8,210 PROD2 DRILL FCO T Got through build section, PUH to 8210 get area clear enough to run liner 03:54 04:30 0.60 8,210 8,700 PROD2 DRILL FCO T RBIH,Set down @ 8238,8253. Clean through 8330 area, head to bottom,8700,pumping sweeps Set down @ 8350 04:30 05:00 0.50 8,700 8,190 PROD2 DRILL FCO T 8700'Chase sweeps to 8190. Clean trip up 05:00 06:30 1.50 8,190 8,700 PROD2 DRILL FCO T 8190'trip in hole. No major set downs while RIH just small bobbles. Page 13 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 8,700 8,700 PROD2 DRILL FCO T Wipe up until pill is ready.-Trap pressure on choke-RIH and swap pumps.Start pumping beaded liner pill 25 bbls at 10.5#followed by clean 10.5#KWF 07:30 10:30 3.00 8,700 56 PROD2 DRILL TRIP P POOH laying in liner beads,pumping .8 bpm, POOH 40 fpm,keeping MPD/ECD @ 11.2.Clean up through window. POOH laying in KWF. Flag EOP 7562' 10:30 12:00 1.50 56 0 PROD2 DRILL PULD P Monitor well for flow-no-flo. Pre-job Lay down BHA#14 12:00 13:30 1.50 0 570 COMPZ CASING PUTB P Pre-iob-P/U BHA#15 with liner assembly(16 joints with 1.5 bent sub&bald-nose shoe) 13:30 15:30 2.00 570 8,170 COMPZ CASING RUNL P RIH pumping 10.5 KWF MPD. Stop @ 8070'correct depth&re-set BHI computer due to WOB problems. repaired.Weight check-28K 15:30 16:30 1.00 8,170 8,682 COMPZ CASING RUNL P Orient liner HS through window- clean,small bobbles at 8220,8250'. Slid down until 8640'.tagged up. P/U weight 35K.Orient made it down to 8650',8672',8682'-P/U weight 32K. Set back down @ 8682'. Open choke, bleed annular. 'w� 16:30 17:30 1.00 8,682 7,784 COMPZ CASING CIRC P BOL-8682'/TOL 8166' ,' Increase pump rate to 1.5 bpm- WOB-4K, P/U weight 26K. Pull up hole 20ft.Set up pits for circulating Drilling mud. Pump 10 bbls visc pill followed by DM. 0.8 bpm in,0.6 bpm out,open choke, BHP 3750, ECD 12 17:30 17:36 0.10 7,784 7,812 COMPZ CASING DLOG P Log Gamma Tie In for+1 foot correction TOL @ 8167/BOL 8683'Corrected 17:36 18:00 0.40 7,812 6,493 COMPZ CASING TRIP P Trip Out of well 18:00 18:30 0.50 6,493 6,463 COMPZ CASING CIRC P Stop and perform P-Test at 6493' MD. 20 Min test 1.38 BPM In 1.37 Out. 8.6 PPG In 8.59 PPG Out. WHP=126 PSI ECD=11.18,28 BBIs In,27.7 Out during test Coil Pressure 3540 TVD=4977 BHP=2890 18:30 19:00 0.50 6,463 6,430 COMPZ CASING CIRC P 10 min test 1.38 BPM In,Out 0.90 bpm WHP=158 Coil Pressure=3480 Pumped for 7 minutes at 1-for-1 returns then bottom fell out Lost 2.5 BBIs in ten minutes. BHP before loss 3067, BHP=2833 with losses 19:00 21:15 2.25 6,430 0 COMPZ CASING TRIP P Trip out of well Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:30 1.25 0 0 COMPZ CASING PULD P On surface, Flo Check well. PJSM Lay down BHA#15 22:30 00:00 1.50 0 0 PROD3 RPEQPI RGRP T Start Injector repairs Begin NAD Downtime 09/05/2010 Complete Injector skate Change out, RIH with nozzle. Perform pressure tests. Pump Hi Vis pills to heal losses. 00:00 06:00 6.00 0 0 PROD3 RPEQPI RGRP T Continue Injector Skate repair NAD Downtime continues 06:00 09:00 3.00 0 0 PROD3 RPEQPI SFTY P Safety round table discsussion.Crew change&tidy up work area before going back to work. 09:00 12:00 3.00 0 0 PROD3 RPEQPI RGRP T Install stripper,Stab Pipe,cut 20 ft of coil off. 12:00 13:00 1.00 0 0 PROD3 RPEQP1RGRP T Install CT connector. Pull test to 40K &pressure test to 3500. 13:00 15:30 2.50 0 43 PROD3 RPEQP1PULD P Back on CPAI Time.Complete making up Connector and BHA string.valve&surface checklist. 15:30 17:45 2.25 43 7,794 PROD3 RPEQP1TRIP P RIH pumping.3 bpm. Full returns to surface. Check Injector&pipe- good.Tie in @ 7770'-6ft correction. Starting getting liner pill returns to surface from previous runs. 17:45 19:45 2.00 7,794 8,148 PROD3 RPEQP1CIRC P 8148, Returns light with shows of crude ship to tiger tank. Circ bottoms up, Increase pump rate from 1 BPM to 1.5 BPM BHP=3373 @ 1.0, BHP=3440 @ 1.5 ,0.7 BPM returns after bring returns back in. 70 bbl sent to tiger tank. 19:45 20:09 0.40 8,148 8,148 PROD3 RPEQP1CIRC P Start pressure test @ 1.5 BPM. BHP is already lower than required. Will do 1 BPM at the end. Rate In 1.5,Out 0.92 Choke Open, WHP=0 BHP=3433, EDC=10.3.Total losses 11.65 20:09 20:36 0.45 8,148 8,148 PROD3 RPEQP1CIRC P Go to step 6 of procedure,pump 30 BBI Hi Vis Pill 20:36 20:45 0.15 8,148 8,148 PROD3 RPEQPICIRC P 5 BBIs out of coil 0.8 BPM in @ 3624,0 bpm out WHP=350 BHP=3524, ECD=10.63 20:45 20:57 0.20 8,148 8,148 PROD3 RPEQPI CIRC P 10 BBIs out of coil 0.8 BPM in @ 3225,0 out WHP=433 BHP=3615, ECD=10.91 20:57 21:09 0.20 8,148 8,148 PROD3 RPEQP1CIRC P 15 BBIs out of coil 0.89 BPM in @ 2912,0 bpm out WHP=459 --PROD3 BHP=3642, ECD=10.99 21:09 21:21 0.20 8,148 8,148 RPEQPI CIRC P 20 BBIs out of coil 0.91 BPM in @ 2627,0 bpm out WHP=446 BHP=3651, ECD=11.02 Page 15 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:21 21:33 0.20 8,148 8,148 PROD3 RPEQP1 CIRC P 25 BBIs out of coil 0.91 BPM in @ 2070,0 bpm out WHP=450 BHP=3642, ECD=10.95 Breaking down.Go to 1.5 BPM and open choke 21:33 23:03 1.50 8,148 8,148 PROD3 RPEQP1 CIRC P Retest step 2 1.5 BPM in @ 2989,0.82 bpm out WHP=0 BHP=3485 ECD=10.51 Suspend test, returns under 0.8 bpm. Mix Second hi-vis pill 23:03 23:33 0.50 8,148 8,148 PROD3 RPEQP1CIRC P Start pump 40 BBI ultra hi vis pill 1.21 BPM @ 2276,0.65 Returns BHP=3394 ECD=10.2 23:33 23:39 0.10 8,148 8,148 PROD3 RPEQP1CIRC P Pill at nozzle Shut in well BHP=3359 ECD=10.3 WHP=0 23:39 23:45 0.10 8,148 8,148 PROD3 RPEQP1CIRC P 5 BBIs out WHP=235 BHP=3513, ECD=10.63 0.8 BPM in @4100 23:45 23:51 0.10 8,148 8,148 PROD3 RPEQP1CIRC P 10 BBIs out WHP=385 BHP=3609, ECD=10.9 0.8 BPM @ 3855 23:51 23:57 0.10 8,148 8,148 PROD3 RPEQP1 CIRC P 15 BBIs out WHP=385 BHP=3648, ECD=11.03 0.8 BPM @3411 23:57 00:00 0.05 8,148 8,100 PROD3 RPEQPITRIP P 20 BBIs out WHP=385 BHP=3648, ECD=11.03 0.8 BPM @3411 POOH for Whipstock Lay in last 20 BBIs Pill 09/06/2010 Complete pressure tests,Set whipstock @ 8147,Complete BOPE Test,Witness waived by Jeff Jones, AOGCC 00:00 02:00 2.00 8,100 0 PROD3 RPEQP1TRIP P Continue out of well 02:00 02:36 0.60 0 0 PROD3 RPEQPI PULD P At surface, PJSM, Lay down BHA #16 Lost 11 BBIs on trip out 02:36 04:06 1.50 0 70 PROD3 RPEQP1PULD P Reconfigure BHA to run Whipstock, P/U Whipstock on BHA#17 04:06 06:51 2.75 70 8,156 PROD3 RPEQP1TRIP P Trip in hole with Whipstock.Tie in-5 ft correction.Weight check 24.5K. RIH to setting depth. Set TF 25 right. 06:51 07:06 0.25 8,156 8,147 PROD3 RPEQP1WPST P Shut down pump,close EDC. 25 Right.Start pumping.6 bpm, pressure increased to 4200psi, setting pressure. Good indication of set-set down 3K WOB,CT weight 4K. TOWS=8147' BOWS 8156' 07:06 09:36 2.50 8,147 62 PROD3 RPEQP1TRIP P POOH-pumping .6 bpm, POOH 80 fpm. Flo-check @ surface. 09:36 10:36 1.00 62 0 PROD3 RPEQPI PULD P lay down BHA-setting tool looked good. 10:36 13:06 2.50 0 0 PROD3 RPEQPI BOPE P **Trap 600 psi on well,close swabs &change out Bravo 5 before BOP test. Page 16 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:06 23:00 9.90 0 0 PROD3 RPEQP1 BOPE P Start testing BOP's.**low 250 High j\ 3500 psi.**State test Waived by Jeff �J Jones. Romeo 2 valve leaking. 23:00 00:00 1.00 0 PROD3 WHPST CIRC P BOPE test complete-all passed. Circ water out of coil, Intall UQC check valves 09/07/2010 Milled window#2. POOH and MU drilling BHA#19 for build section. RIH and start drilling build section. 00:00 01:00 1.00 0 73 PROD3 WHPST WPST P M/U window milling BHA,0.6 degree motor,2.80 diamond window mill, 2.79 string reamer 01:00 03:30 2.50 73 7,805 PROD3 WHPST TRIP P Trip in well to mill window 03:30 04:00 0.50 7,805 8,140 PROD3 WHPST TRIP P Log GR tie-in,-2ft correction.Close EDC. Up wt 28.5K. RIH to dry tag. Pinch point depth 8147.6'. PUH up wt 30K. 04:00 06:00 2.00 8,140 8,148 PROD3 WHPST MILL P Start pumping 1.4 bpm, FS 2800 psi. RIH,WOB @ 8147.6',motor stall. PUH, 1.5 bpm, FS 2950 psi. RIH to 8147.4'.Start time drilling,4 min/0.1'.Tagged at 8147.6'and stalled motor. PUH, pumping 1.45 bpm, FS 2980 psi. RIH to 8147.3'.Start time drilling,6 min/0.1'. PUMPING 1.45 BPM-0.6 BPM RETURNS Tagged at 8147.6',WOB 1.5K, motor stall. PUH 06:00 11:30 5.50 8,148 8,150 PROD3 WHPST MILL P Started milling better from 8147.6'. 1.40 bpm,3100 psi, .6 bpm out, WOB 1.6K.Ct weight 9K.Going well 2K down-auto driller mode.Start pumping Biozan-water. 11:30 12:30 1.00 8,150 8,153 PROD3 WHPST MILL P 8152.8.Mill exit casing(BOW) 12:30 14:30 2.00 8,153 8,154 PROD3 WHPST MILL P String reamer out. Mill @ 2fph 14:30 15:30 1.00 8,154 8,164 PROD3 WHPST MILL P 8157.8 End of 2'/Hr portion. Beginning drilling rathole 15:30 16:30 1.00 8,164 8,164 PROD3 WHPST REAM P 8164 Start backreaming hole/ window passes 3 times. Dry drift through window-clean. 16:30 18:30 2.00 8,164 73 PROD3 WHPST TRIP P POOH 18:30 20:15 1.75 73 62 PROD3 WHPST PULD P At surface. PJSM, LD milling BHA #18. MU BHA#19 20:15 21:15 1.00 62 62 PROD3 DRILL PULD T On surface EDC failed. PJSM,swap out EDC,surface test 21:15 23:40 2.42 62 8,164 PROD3 DRILL TRIP P Open EDC. RIH with drilling BHA #19.Tie-in-1 ft correction.Closed EDC. RIH pumping min rate. 23:40 23:59 0.33 8,164 8,171 PROD3 DRILL DRLG P Pumping 1.4 bpm, returns 0.5 bpm, FS 2770 psi. WOB 1.5K, motor work= 175 psi, ROP 50 fph. Stalled motor, PUH up wt=27K. RIH start drilling Page 17 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/08/2010 24 hr Summary Drilled build section. POOH and MU lateral drilling BHA. Drilled AL1-01 lateral to 8627' 00:00 01:20 1.34 8,171 8,210 PROD3 DRILL DRLG P Stalled at 8180', PUH. RIH.WOB 1.0K, FS 2750 psi,motor work=100 psi. Pumping 1.4 bpm, returns 0.7 bpm. 01:20 01:55 0.59 8,210 8,210 PROD3 DRILL DLOG P Correlation trip for RA markers. PUH to 7780',up wt=26K. RIH,4 fpm,tie-in 0 ft correction. RA marker correlation=8152.5' 01:55 02:49 0.91 8,210 8,224 PROD3 DRILL DRLG P Pumping 1.4 bpm,returns 0.65 bpm, FS 2700 psi. WOB 1.5K,motor work=200 psi, ROP 60 fph. 10.4 ppg ECD with no choke,0.85 bpm returns. 10.61 ppg ECD with 150 psi choke, 0.25 bpm returns. 10.57 ppg ECD with 100 psi choke, 0.40 bpm returns. 10.54 ppg ECD with 50 psi choke, 0.55 bpm returns. 10.51 ppg ECD with 25 psi choke, 0.65 bpm returns. Continue drilling build with with 25 psi back pressure. 02:49 05:49 3.00 8,224 8,245 PROD3 DRILL DRLG P ROP slowed to 5 fph @ 8224',WOB 2.4K, motor work=120 psi. 05:49 06:34 0.75 8,245 8,269 PROD3 DRILL DRLG P Drilling break, ROP=30 to 40 FPH 1.4 BPM @2698 FS BHP=3532 06:34 07:04 0.50 8,269 8,277 PROD3 DRILL DRLG P Back in the hard/shale stuff ROP 5 FPH 07:04 09:55 2.85 8,277 8,370 PROD3 DRILL DRLG P 8277 ROP up to 45FPH 1.39 BPM @ 2698PSI FS Drill Zone at bit, BHP=3552 09:55 12:10 2.26 8,370 0 PROD3 DRILL TRIP P End of build POOH for lateral BHA Open EDC above window PUW=26K Follow MP schedule 12:10 15:40 3.50 0 72 PROD3 DRILL PULD P At surface, PJSM, Un Deploy build section BHA Deploy lateral BHA#20 with 1.0 degree motor&resistivity 15:40 18:13 2.55 72 8,370 PROD3 DRILL TRIP P Trip in well.Tie-in-2 ft correction 18:13 21:28 3.25 8,370 8,520 PROD3 DRILL DRLG P Drilling ahead.WOB 2.5K, motor work 200 psi,60 fph. 1.4 bpm w/0.95 bpm returns with FloPro, ECD 10.6 ppg with no back pressure. 21:28 22:13 0.75 8,520 8,520 PROD3 DRILL WPRT P Wiper trip#1 and MAD pass. PUH, up wt=27K. PUH to 8172', RIH. 22:13 23:13 1.00 8,520 8,574 PROD3 DRILL DRLG P Drilling ahead. FS 2900 psi.WOB 2K,motor work 300 psi, 80 fph. Pumping 1.44 bpm-0.90 bpm returns, ECD 10.65 w/0 psi WHP. Page 18 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:13 23:58 0.75 8,574 8,627 PROD3 DRILL DRLG P Pick up off bottom to check orientator. Continue drilling ahead. 09/09/2010 Drilled AL1-01 lateral from 8627'to 9420'. 00:00 00:39 0.66 8,627 8,670 PROD3 DRILL DRLG P Drilling ahead.WOB 2K,motor work =300 psi,65 fph. Pumping 1.43 bpm-0.93 bpm returns, ECD 10.7 ppg,0 psi WHP. 00:39 01:19 0.67 8,670 8,670 PROD3 DRILL WPRT P Wiper trip, up wt=27K, PUH @ 20 fpm to 8260', RIH 01:19 03:14 1.92 8,670 8,755 PROD3 DRILL DRLG T FS 2950 psi. Drilling ahead.WOB 1.7K, motor work=300 psi,70 fph. Pumping 1.40 bpm-0.94 bpm returns, ECD 10.8 ppg,0 psi WHP. Note:Coded as Trouble Time for re-drilling of hole lost in AL1-PB1. 03:14 04:39 1.42 8,755 8,780 PROD3 DRILL DRLG T Drilling break at 8755'. ROP 20 down to 5 fph.WOB 2.5K,motor work 250 psi. Pumping 1.4 bpm-1.0 bpm returns, ECD 10.85,0 psi WHP. 04:39 05:13 0.57 8,780 8,821 PROD3 DRILL DRLG T Drilling ahead,WOB 2K,motor work 300 psi, ROP 80 fph. Pumping 1.4 bpm-1.0 bpm returns, ECD 10.83 ppg,0 psi WHP. 05:13 06:43 1.50 8,821 7,100 PROD3 DRILL WPRT T Wiper trip#3 up to 7100'. 06:43 06:58 0.25 8,177 8,200 PROD3 DRILL DLOG T Log tie in @ 8177 for 0 zero...zip...nada correction. Continue on wiper trip 06:58 07:43 0.75 8,200 8,821 PROD3 DRILL WPRT T Continue in well, clean trip through window.Set downs and overpulls between 8750 and 8768. Back ream this area after we got through. 07:43 10:13 2.50 8,821 8,947 PROD3 DRILL DRLG T 8821',drill ahead 1.40 BPM @ 2900 FS BHP=3599 EDC=10.9 ROP=30 FPH 10:13 10:49 0.60 8,947 8,970 PROD3 DRILL DRLG T 8947', BHA wiper,Stacking PUW=27 1.4 BPM @ 3120PSI ECD=10.9 BHP=3638 1 BPM returns 10:49 11:43 0.90 8,970 8,970 PROD3 DRILL WPRT T Wipe to 8250 PUW=27K BHP=3639 Fairly smooth through 8750 Area 11:43 13:49 2.10 8,970 9,120 PROD3 DRILL DRLG T 8970' Drill Ahead 1.42 BPM @ 2950 FS BHP=3638, 1 BPM Out 13:49 14:58 1.15 9,120 9,120 PROD3 DRILL WPRT T 9120,Wipe to 8250 PUW=27K Ratty going back in, Back ream low side 8800 to 8730 14:58 17:18 2.34 9,120 9,270 PROD3 DRILL DRLG T 9120',drill ahead 1.4 BPM @ 2950 FS RIW=6K,WOB=1.4K ROP=60 to 90 FPH BHP=3671 ECD=11, 1 BPM returns 17:18 20:12 2.91 9,270 9,270 PROD3 DRILL WPRT P Wiper trip up 7100'. Up wt 26K. RIH,tie-in+0.5 ft correction. Lost weight @ 8758', continue RIH Page 19 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:12 23:17 3.09 9,270 9,420 PROD3 DRILL DRLG P FS=3050 psi. Drilling ahead. WOB 1.5K, motor work 220 psi, ROP 40 fph 1.40 bpm w/1.05 bpm returns, ECD 11.1 ppg,0 psi WHP. 23:17 23:57 0.67 9,420 8,545 PROD3 DRILL WPRT P Wiper trip to 8570' PUW=27.5K, FS=3200 psi 09/10/2010 Fluid losses while circulating KWF with liner beads.Swap hole back to 8.6 ppg FloPro.Wiper trip to clean well. 00:00 01:00 1.00 8,545 9,420 PROD3 DRILL WPRT P RIH,wiper trip up to 8270'. Wt bobbled at 8744'to 8780'while pumping 1.2 bpm 01:00 02:00 1.00 9,420 9,495 PROD3 DRILL DRLG P FS=3250.WOB=1.8,motor work 300 psi, ROP 70 fph 1.43 bpm w/1.15 bpm returns, ECD 11.26,0 psi WHP 02:00 02:15 0.25 9,495 9,495 PROD3 DRILL WPRT P Losing wt, mini wiper up to 9420'. RIH 02:15 03:10 0.92 9,495 9,575 PROD3 DRILL DRLG P Drilling ahead.WOB 2.4K,motor work 300, ROP 65 fph. 03:10 03:25 0.25 9,575 9,575 PROD3 DRILL EQRP T Rig lost highline power.Start up diesel generators. Unable to move coil or circulate during this time. 03:25 03:40 0.25 9,575 9,575 PROD3 DRILL WPRT P On rig power. WOB stacked out to 6K. Pulled heavy 40K, PUW 26K. Mini wiper for 100'. RIH, FS=3100, 1.40 bpm w/0.78 bpm returns. 03:40 03:45 0.09 9,575 9,580 PROD3 DRILL DRLG P Drilling ahead.WOB 1.5K, motor work 240 psi, ROP 70 fph. 1.4 bpm w/0.85 bpm returns. ECD 11.18 TD lateral @ 9580' 03:45 05:45 2.00 9,580 8,167 PROD3 DRILL WPRT P Wiper trip while pumping 5 bbl lo-vis followed by 12 bbl of hi-vis. Pull up to 9200', RIH at bottom while vis pills exit. Wiper trip up to 7100'. 05:45 07:15 1.50 8,167 7,100 PROD3 DRILL WPRT P Pulling heavy at window,8167& 8165 slow speed and recip. PU through window Get above window,circulate.Open EDC continue up to 7100 07:15 08:00 0.75 7,100 8,755 PROD3 DRILL WPRT P 7100', RBIH Closed EDC and tie in for-1' correction 08:00 09:45 1.75 8,755 9,301 PROD3 DRILL REAM P 8755 Tag up,work pipe through to 8807'. Back ream hole.Overpulls @ 8745&8740 continue to work this area 09:45 10:30 0.75 9,301 9,581 PROD3 DRILL REAM P Tag up @9288&9301 work this area BHP=3624 10:30 11:06 0.60 9,581 9,581 PROD3 DRILL WPRT P Tag TD,Corrected TD 9581 PUH Start 10.5 Beaded liner pill down Page 20 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:06 11:59 0.89 9,581 7,777 PROD3 DRILL TRIP P Trip out of well laying in 10.5 Beaded Pill return rate falling 11:59 15:29 3.50 7,777 7,866 PROD3 DRILL TRIP T Overpull in cased hole 12K over. No WOB or DH Pressure change. Not packed off but no returns to surface. Suspect cuttings bed. RBIH swap back to 8.5 ppg to try and get returns. Low on mud volume. Pump 0.6 bpm as return rate gradually increases.Get 10.5 ppg fluid back at surface 15:29 16:59 1.50 7,909 8,153 PROD3 DRILL FCO T Have mud onboard, Returns back down to 8.8 ppg 1 BPM in, .64 out Pull up hole to 7100'. BHP=3420 16:59 18:29 1.50 8,153 9,580 PROD3 DRILL TRIP T Stack out in window area. Had correct orientation,pumps were down. Unable to orient&motor stalled. RIH at min rate,stacked out several times,eventually worked through window. Continue RIH 18:29 21:09 2.68 9,580 8,145 PROD3 DRILL WPRT T Start displacing well to 8.6 ppg FloPro. Initial pump rate 1.0 bpm-0.3 bpm returns,as the well filled with FloPro return rate increased. Pump rate w/well full of FloPro 1.14 bpm in-0.95 bpm out. Pump viscous sweeps and wiper trip to surface. 21:09 21:13 0.07 8,145 8,138 PROD3 DRILL WPRT T PUW 24K, pulled heavy to 29K coming through window. RIH,start rolling pumps,pulled heavy again, came up through window on 3rd attempt. 21:13 23:58 2.75 8,138 3,040 PROD3 DRILL WPRT T PUH pumping 1.5 bpm increasing choke pressure to maintain returns at 1 bpm. Seeing large amount of cuttings in the returns even while circulating in the tubing while POOH. Continued all the way up to—5000'MD,tapered off above that. 09/11/2010 Landed liner for AL1-01 lateral. Displaced well to diesel from 8100'. 00:00 01:30 1.50 3,040 67 PROD3 DRILL WPRT T PUH,wiper trip with FloPro. Light amount of cutting in the returns.Tag up on surface. 01:30 02:35 1.09 72 4,548 PROD3 DRILL WPRT T Reset depth, RIH at 80 fpm pumping 0.45 bpm in-0.40 bpm returns,660 psi WHP. 02:35 02:45 0.17 4,547 4,547 PROD3 DRILL SVRG T Injector head servicing and inspection 02:45 03:30 0.75 4,547 7,800 PROD3 DRILL WPRT T RIH at 80 fpm,0.48 bpm in-0.38 bpm returns, 350 psi WHP. Page 21 of 23 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 7,800 9,581 PROD3 DRILL WPRT T Tie-in-oft correction @ 7800'. Slow RIH speed to 25 fph,pass through window clean. Passed through previous problem areas at 8750'and 9300'no problem. 04:30 05:04 0.58 9,581 9,581 PROD3 DRILL CIRC T Tagged TD at 9581'.Complete mixing FloPro with liner beads and pump to bottom. 05:04 06:28 1.40 9,581 8,072 PROD3 DRILL TRIP T Laying FloPro with liner beads. Pumping 0.3 bpm, PUH at 22 fpm. Clean trip up through window 06:28 06:58 0.50 8,072 6,672 PROD3 DRILL DLOG P Paint EOP flag 06:58 08:58 2.01 6,672 71 PROD3 DRILL TRIP P Continue to surface laying in 10.5 ppg fluid 08:58 09:58 1.00 71 71 PROD3 DRILL PULD P At surface, PJSM, Flo Check wellLay down BHA#20 09:58 10:13 0.25 71 0 COMPZ CASING SFTY P PJSM to run liner/Fill Hole 10:13 10:58 0.75 0 0 COMPZ CASING PUTB P P/U AL1-01 Liner 10:58 11:13 0.25 0 0 COMPZ CASING SFTY P BOP Drill/P/U safety joint and deploy 11:13 12:58 1.75 0 1,418 COMPZ CASING PUTB P Continue picking up liner 12:58 13:43 0.75 1,418 1,418 COMPZ CASING RUNL P R/D floor/prep injector Stab on to liner, Surface test,Strip on,Tag up&set depth 13:43 15:28 1.75 1,418 8,075 COMPZ CASING RUNL P RIH, EDC Closed, .25 BPM on 10.5 15:28 15:34 0.10 8,075 8,072 COMPZ CASING DLOG P Stop and correct to flag-2 PUW=29K RIH with Liner 15:34 16:19 0.75 8,072 9,561 COMPZ CASING RUNL P Run liner to set depth, Pump off 1.4 BPM @ 3165, PUW=27K. Liner set 8144'-9561'. PUH to tie in 16:19 16:49 0.50 9,561 7,808 COMPZ CASING DLOG P 9205 Log tie in for no correction. Remove liner length from counters. 16:49 20:43 3.90 7,808 8,100 COMPZ CASING CIRC P RBIH to 8100'.Start pumping 8.6 Flo Pro try to recover 10.5 ppg KWF. Pump 15 bbl viscous pill,5 bbl KCL water,followed by diesel. Circulate diesel to surface.WHP increased to 1100 psi. 20:43 22:58 2.25 8,100 50 COMPZ CASING TRIP P Start POOH 30 fpm, returns SI, pumping 0.3 bpm diesel,WHP 1100 CT pullling heavy 44K, PUW gradually dropped down to 27K by 5800'. 22:58 23:58 1.00 50 50 COMPZ CASING PULD P Liner BHA#21 at surface.Shut in WHP=920 psi. PJSM,press undeploy BHA. 09/12/2010 Rigged down and moved off 3N-16A. CDR2 Rig release @ 09:00 am 9/12/2010 00:00 00:30 0.50 50 0 COMPZ CASING PULD P Continue pressure undeploy liner running BHA#21 Page 22 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 0 0 COMPZ CASING PULD P Lay down BHA#21 01:00 02:30 1.50 0 0 DEMOB WHDBO NUND P PJSM. PU lubricator. Set BPV. LD lubricator 02:30 09:00 6.50 0 0 DEMOB WHDBO NUND P Flush lines, blowdown BOP stack, start rigging down for rig move. Rig Release @ 09:00 Page 23 of 23 Page 1 of 1 pi D Z/0 - Schwartz, Guy L (DOA) /v 7 From: Schwartz, Guy L(DOA) Sent: Tuesday, August 31, 2010 9:42 AM To: 'Eller, J Gary' Subject: RE: Change in Planned KOP for 3N-16AL1-02 (#210-109) Gary, I reviewed the well file to compare the original completion with the new drawing. The additional window(using a flow thru whipstock) is acceptable as it doesn't move the BHL locations >500' and will not require any permit updates. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, 3 Gary [mailto:J.Gary.Eller @conocophillips.com] Sent: Monday, August 30, 2010 1:30 PM To: Schwartz, Guy L(DOA) Subject: Change in Planned KOP for 3N-16AL1-02 (#210-109) Guy—Howdy! I wanted to keep you posted on a change in plans for the kickoff point of the KRU 3N-16AL1-02 CTD lateral (PTD#210-109). The original plan was to have this lateral kick out of the AL1 lateral at a depth of 8240' MD. Because of hole conditions, we now want to make a second window exit from the 3N-16A motherbore at a depth of 8144' MD. The attached schematic should clarify the change we intend to make(color scheme is yellow/black is complete, and blue is proposed). Thanks, and please let me know if you have any questions. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 8/31/2010 ° l - ❑ ❑ ° ❑ \ 2 2 ❑co o o_ o m o co co En co rn CO m n' `m co M I� © nm Iii CI^ N O NTCO N I- ' O O =,c-'.? d Q N Q QJ am Qm c) a n r w � 113i a a p rn O _ U NC�OO]\\ m ❑ V p C co °° w E o U o �� h °v y N A U O ` G W O E m a = in N N ' H cn J ry V flU m L X N d N i L V/ __ G /1/ 4 in I ` \II U i / 2 f 0 3 2 o J O O d Ci- I o m❑ 1 2.1 h o � co v E E "Ell m Q H N co: �LppD�`;CO co c7, V V V N T N G CO a `m a `m o Q Om Om Am M SIfETE o ALASEA 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, 3N-16AL1 ConocoPhillips Alaska, Inc. Permit No: 210-107 Surface Location: 1561' FSL, 30' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 242' FNL, 768' FEL, SEC. 33, T13N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new welibore segment of existing well KRU 3N-16A, Permit No 210- 049, API 50-209-21593-01. 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 7 day of August, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECE I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4013 1 1 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska i &l Ca:Cam,Commission la.Type of Work: 1 b.Pro osed Well Class: Develo ment-Oil Service-Win' Sin le Zone 1 c.S eci ��wel�4is f osed for. p P ❑ I 9 0. P fy p oP Drill ❑ Re-drill El 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 u Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 3N-16AL1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9593'. TVD: 6435'. Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1561'FSL,30'FEL,Sec.29,T13N,R9E,UM . ADL 25521,25520 - Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 572'FNL, 1938'FEL,Sec.33,T13N,R9E,UM 2556,2557 8/28/2010 - Total Depth: 9.Acres in Property: 14.Distance to 242'FNL,768'FEL,Sec.33,T13N,R9E,UM 2560 Nearest Property: 8130 • 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 60 feet 15.Distance to Nearest Well Open Surface:x- 518371 . y- 6013799' Zone- 4 GL Elevation above MSL: 34 feet . to Same Pool: 3N-15,1350' 16.Deviated wells: Kickoff depth: 8170 -ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 950 deg Downhole:3283 psig • Surface:2663 psig • 18.Casing Pro ram: 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 808' 8785' 6435' 9593' 6435' slotted/solid 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) 8190 6478 4900' 8157 6453 Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 249 sx CS II 115' 115' Surface 4760' 9.625" 1350 sx AS III,350 sx Class G 4797' 3638' Intermediate Production 4963' 7" 300 sx Class G, 175 sx AS I 5000' 3752' Liner 3524' 3.5" 600 sx Class G 8190' 6478' Perforation Depth MD(ft): Perforation Depth ND(ft): none none 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program 5 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: C 22. I hereby certify that the foregoing is true and correct. Contact Gary Eller @ 263-4172 e` Printed Name V. Cawvey Title Alaska Wells Manager Signature Aginiiiva 41/ �.�VMC Phon 265-6306 Date 8//0//0 Commission Use Only Permit to Drill API Number: Permit Approval ISee cover letter 7 `._ ' / ( Op for other re uirements Number: ZlC_,� /L�F7 50-(�e�,.� �5� �r�'(���'� �! Date: L� q Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 3sod rSi &VP e5 f Samples req'd: Yes H. No 121 Mud log req'd: Yes ❑ No g Other: *2566 jO se: A•�n n� " •_C"..- 12S measures: Yes El No ❑/� Directional svy req'd: Yes 7 No ❑ n AA,.-.,i�r...t-:ut A,,/ra glue' /'e0"j-ref �o:Q.-6n0'e. r,�,�f•'a n. C o►,,nr a hce-s- ttf IT r Gt li�'UX , A/ - u/-Fi m.4c ...p-e.,-..-7--,4... ; 4LCcd / �-v l APPROVED BY THE COMMISSION / 4- DATE: �` COMMISSIONER I Form 10-401 (Revised 7/2009) This permit is valid f r ,nt sr t el a= ,f pproval(20 AAC 25.005(g)) Su it n uplip�tie7 �� �` j' /3./0 6,-,(3 / Conoco Phillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 10, 2010 RECEIVED Commissioner-State of Alaska 2010 Alaska Oil &Gas Conservation Commission Cpj$Sian 333 West 7th Avenue Suite 100 ( Skg "�u Qó� ' Anchorage, Alaska 99501 ,;yCt; fgQ Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for four coiled tubing drilling (CTD) laterals out of Kuparuk Well 3N-16A (PTD#210-049) using the coiled tubing drilling rig, Nabors CDR2-AC. The 9 9 9 9 objective is to drill four A-sand laterals for waterflood injection: 3N-16AL1, 3N-16AL1-01, 3N-16AL1-02, and 3N- 16AL1-03. Work is scheduled to begin in late August 2010. Please note that the packer placement in well 3N-16A is not as prescribed in 20 AAC 25.412(b). During the rotary sidetrack which set up these CTD laterals we repeatedly tried to run 5%" casing which would have allowed a packer to be set within 200' of the kickoff point. We ultimately ran 3'/%" liner which forced placement of the liner-top packer substantially more than 200' away from the planned kick-off point of the CTD laterals. ConocoPhillips drilling engineers kept AOGCC staff apprised of the problems and subsequent changes in the completion plan for KRU 3N-16A. Administrative approval is requested to allow water injection into the 3N-16A CTD laterals given the existing packer placement. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 3N-16AL1, 3N-16AL1-01, 3N-16AL1-02, 3N-16AL1-03 — Proposed &Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations, including quarter-mile review — Directional Plans If you have any questions or require additional information please contact me at my office 907-263-4172. .ncerely, Gary Eller ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 3N-16AL1, AL1-01, AL1-02, AL1-03 — Coiled Tubing Drilling Summary of Operations: Well 3N-16A is a recent rotary sidetrack equipped with 3%2"tubing and 3'/2"production liner.Well 3N-16A has not been perforated—it was drilled to the top of the A-sand and cased/cemented in anticipation of future CTD operations. Four proposed A-sand CTD laterals will access an area that is without injection support for improved sweep efficiency and reserve recovery. Prior to drilling the 3N-16A CTD sidetracks, service coiled tubing will drill out the shoe track of the 31/2" production liner. Well 3N-16A has already passed an MIT-IA and MIT-T, and has had a cement bond log run confirming excellent cement. Please note that the packer placement in well 3N-16A is not as prescribed in 20 AAC 25.412(b): it is substantially more than 200' away from the planned kick-off point for the CTD laterals. Administrative approval is requested to allow water injection into the 3N-16A laterals given the existing packer placement. The 3N-16AL1 lateral will exit the 3'/2"liner via a mechanical whipstock at 8170' MD. The lateral will target the A2 sand northeast of the existing well with a 1423' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9593' MD with a liner top aluminum billet at 8785' MD. • The 3N-16AL1-01 lateral will kick off from the aluminum billet at 8785' MD and will target the A3 sand northeast of the existing well with a 940' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9725' MD with a liner top aluminum billet at 8240' MD. The 3N-16AL1-02 lateral will kick off from the aluminum billet at 8240' MD will target the A2 sand southeast of the existing well with a 1099' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9339' MD with a liner top aluminum billet at 8440' MD. The 3N-16AL1-03 lateral will kick off from the aluminum billet at 8440' MD and will target the A3 sand southeast of the existing well with a 948' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9388' MD with the final liner top located just inside the 31/2" liner at 8165' MD. CTD Drill and Complete 3N-16A Laterals: August 2010 Pre-Rig Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. MIT-IA,MIT-T,MIT-OA.. > 3. MIRU coiled tubing. Drill out the 31/2" liner shoe from 8157' to 8190' using a 2.80"mill 4. PU under-reamer dressed for 31/2", 9.3 ppf tubing. Under-ream cement sheath in liner shoe.-- 5. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 35 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. - L ( 2. 3N-16AL1 Lateral(A2 sand,northeast) • .3 a. Set a mechanical whipstock in the 31/2"liner at 8170' L ' b. Mill a 2.80"window in the 3 liner at 8170' 1.6 c. Drill 2.70"x 3"bi-center lateral to TD of 9593' MD P t P d. Run 2%" slotted liner with an aluminum liner-to. billet from TD u. to 8785' 3. 3N-16AL1-01 Lateral (A3 sand,northeast) a. Kick off of the aluminum billet at 8785' MD b. Drill 2.70"x 3"bi-center lateral to TD of 9725' MD 3n-P, c. Run 2%" slotted liner with an aluminum liner-top billet from TD up to 8240' Page 2 of 6 OR ! G I N A August 10, 2010, FINAL KRU 3N-16AL1, AL1-01, AL1-02, AL1-03 — Coiled Tubing Drilling 4. 3N-16AL1-02 Lateral(A2 sand, southeast) a. Kick off of the aluminum billet at 8240' MD b. Drill 2.70"x 3"bi-center lateral to TD of 9339' MD c. Run 2%" slotted liner with an aluminum liner-top billet from TD up to 8440' 5. 3N-16AL 1-03 Lateral(A3 sand, southeast) a. Kick off of the aluminum billet at 8440' MD b. Drill 2.70"x 3"bi-center lateral to TD of 9388' MD c. Run 2%" slotted liner from TD up to 8165' MD,up inside the 3%"liner 6. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Run GLVs 4. Flow back well for clean up prior to putting on injection 5. Conduct MIT-IA 6. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- based Flo-Pro mud (8.6 ppg)for drilling operations. The SCSSV installed in 3N-16A should allow us to deploy 2%" slotted liner without having to kill the well. . 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. Casing Program: • 3N-16AL1: 2%", 4.7#, L-80, ST-L slotted/solid liner from 8785' MD to 9593' MD • 3N-16AL1-01: 2%", 4.7#, L-80, ST-L slotted/solid liner from 8240' MD to 9725' MD • 3N-16AL1-02: 2%", 4.7#,L-80, ST-L slotted/solid liner from 8440' MD to 9339' MD • • 3N-16AL1-03: 2%", 4.7#,L-80, ST-L slotted/solid liner from 8165' MD to 9388' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi • Production: 7", J-55, 26 ppf Burst 4980 psi Collapse 4320 psi Liner" 3'/2", L-80, 9.3 ppf Burst 10,160 psi Collapse 10,530 psi Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. . Reservoir Pressure • There have not been any pressure surveys taken in 3N-16A since it has never been perforated. Recent pressure surveys in the target fault block indicate very low bottom hole pressure. A survey in 3N-19 • measured A-sand reservoir pressure of 1252 psi at 6346' SSTVD, corresponding to 3.8 ppg EMW. The . last pressure survey in 3N-15 measured pressure of 1001 psi at 6400' SSTVD, corresponding to 3.0 ppg. . We generally expect to encounter similar pressure as the laterals are drilled away from the/mother well. tv/ccc e,ir ihlcc�ori Page 3 of 6 I Mto L August 10,2010, FINAL KRU 3N-16AL1, AL1-01, AL1-02, AL1-03 — Coiled Tubing Drilling Well Control: • Two well bore volumes(-170 bbl)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 3500 psi. Maximum potential surface pressure in 3N-16A is 2663 psi assuming a gas gradient to surface and maximum • potential formation pressure. Maximum potential formation pressure is based on the original pressure measured in well 3N-19,which is 3283 psi at 6200 SSTVD (i.e. 10.2 ppg)in February 2002. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 3N-16AL1, plan#4 2. 3N-16AL1-01, plan#5 3. 3N-16AL1-02,plan#6 4. 3N-16AL1-03, plan#5 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • • 3N-16A northeastern CTD laterals(ALl &AL1-01): 8130' to property line,—1350' to well 3N-15 • 3N-16A southeastern CTD laterals(AL1-02 &AL1-03): —8800' to property line, 1600' from well 3N-19 Hazards • Lost circulation is a major concern in 3N-16A because of the very low reservoir pressure in the A-sand. • Losses will be tolerated as best as is possible,but if it becomes impossible to drill ahead then we'll complete the well with slotted liner across whatever hole has been drilled. We could then return to drill the remaining laterals after the well has been on injection for a significant period of time. • Shale stability is a potential problem,particularly in the build section where the AS shale will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle. • There has been no injection into the target fault block nor has the 3N drillsite ever been equipped to inject MI gas. Therefore, it is unlikely that an influx could yield significant quantities of gas. • • Well 3N-16A has no measured H25 since it has not been perforated or produced since being sidetracked in July 2010. Prior to being sidetracked well 3N-16 had 140 ppm measured H2S as of 12/15/08. Well 3N-15 is located 25' to the right side and 3N-17 is 25' to the left side of the 3N-16A surface location. Well 3N-15 has 150 ppm H25 and 3N-17 has 120 ppm H2S, both being measured in Nov-09. The maximum H2S level on the pad is 220 ppm from well 3N-01 (12/11/09). All H25 monitoring equipment , will be operational. 0 ""1 Page 4 of 6 St N AL August 10, 2010, FINAL KRU 3N-16AL1, AL1-01, AL1-02, AL1-03 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. • Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow 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 installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. The SCSSV in well 3N-16A will enable us to deploy slotted liner without having to kill the well. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 1200 psi at 8170' MD(6403' SSTVD), or 3.6 ppg EMW. • • Expected annular friction losses while circulating: 819 psi(assuming annular friction of 100 psi/1000 ft due to the 3'A"tubing) • Planned mud density of 8.6 ppg equates to 2870 psi hydrostatic bottom hole pressure at 6403' SSTVD • • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3689 psi or 11.1 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 3N-16A. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,---820 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Quarter-Mile Injection Review A0 The following wells lie within one-quarter mile of the proposed 3N-16A CTD laterals. • 3N-16(plugged& sidetracked)—Plugged A-sand and C-sand perfs in April/May 2010 in anticipation of a rotary sidetrack. Placed a total of 30 bbl of class `G' cement and achieved 1500 psi squeeze pressure. • 3N-16A(suspended injector and motherbore of the CTD laterals). This well was recently TD'd and cased down to 8190' MD, 6478' TVD which is in the B-sand above the target horizon of these CTD laterals. The cement bond log of 7/22/2010 shows generally excellent cement across the 3'/2" liner up to 5564' MD. A liner-top packer at 4666' MD ties the 3'/2" liner into the 7"casing. The well has already passed a MIT-IA(7/11/10)and State-witnessed MIT-T(8/7/10). The passing MIT-T confirms liner integrity between the top of cement at 5564' and the liner-top packer at 4666'. Please note that ConocoPhillips requests administrative approval to allow waterflood injection into 3N-16A even though the packer is more than 200' away from the kick-off point as per 20 AAC 25.412(b). • 3N-16A-PB1—Drilled from 4950' to 8260' MD(6478' TVD). It was TD'd in the B-sand above the target injection horizon of these CTD laterals. The borehole was abandoned due to shales falling apart. • Ultimately stuck 5'/2" liner in this borehole from 5328' —7528'. A cement retainer was set inside the 5'/2" liner at 5360' MD. It is highly likely that sloughing shales will have packed off against the 5'/2" liner, preventing fluid migration uphole to other hydrocarbon bearing intervals. Page 5 of 6 0RIGINAL August 10,2010, FINAL KRU 3N-16AL1, AL1-01, AL1-02, AL1-03 — Coiled Tubing Drilling • 3N-16A-PB2—Accidentally sidetracked from the 3N-16A-PB 1 wellbore at 7740' MD and drilled to 7833' MD(6249' TVD)before confirming accidental departure. It was TD'd in the D-shale above the target injection horizon of these CTD laterals. The 51/2" liner that got stuck in the 3N-15A-PB1 borehole straddled the sidetrack point of this plugback, so likewise it should provide isolation to uphole intervals. Also, since this plugback was TD'd 214' vertically above the proposed kickoff depth of the 3N-16A CTD laterals there should be no opportunity for direct communication with the CTD laterals. • 3N-16A-PB3—Sidetracked from the 3N-16A-PB1 borehole from 5195' to 8180' MD (6472' TVD). It was TD'd in the B-sand above the target injection horizon of these CTD laterals. Abandoned due to . shales falling apart. Placed a 36 bbl cement plug from 6600'—7600' MD. Also set a cement retainer inside the 7"casing at 4900' MD, and squeeze 51 bbl of cement through this retainer. • 3N-14A—Sidetracked from the 3N-14 wellbore in October/November 2007 and drilled to 8220' MD (6647' TVD). This well is a producing single completion in the Kuparuk A-sand. The Kuparuk sands . are isolated by cemented 31/2" liner. • 3N-14A-PB1—Hole was drilled to 7768' MD, 6232' TVD in October 2007. The 5'/2 liner became stuck at 4310' to 7274'. A stinger was used to spot a 21.4 bbl cement plug on top of the stuck liner in order to isolate the plugback and kickoff the 3N-14A borehole. Since this plugback was TD'd 231' vertically above the proposed kickoff depth of the 3N-16A CTD laterals there should be no opportunity . for direct communication with the CTD laterals. • 3N-15—This well is a producing single completion in the Kuparuk A-sand. It is isolated by cemented 7"casing across the Kuparuk sands. OR 1 G I N L Page 6 of 6 August 10, 2010, FINAL 7 KU P 3N-16A CanacoPhillips f 1{ Weil Attributes Max Angle&MD TD 1 Wellborn API/UWI Field Name Well Status Ind r) MD(R OMB) Act Sim KB) a{flSiu' _ / 50025211:5301 KUPARUK RIVER UNI r PROD 56.10 14,69229 _ 8190.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:I RDP 140 1215'2008 Last WO: 7/3/2010 39.49 _5/20/1986 Wei COnfi9-..181-265.7✓]50Q1g,1p,5623AM – -- -_— gg)801419,At'Da_. Annotation Depth(CKB) End Date Annotation I Last Mod.. End Date Lost]ag SLM I 8,143.0 7:13 2010 Rev Reason WORKOVER,SIDETRACK 1 Imosbor 7/14/2010_ 'I' - Casing Strings -.__ —_.._ _-_ -_.... SAIVGF:-/,11 1:' ■ Casing Description String 0... String ID...Top(flKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H-40 WELDED ._.._.-_ Cuing Description String 0... String ID...Top NOM) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd - SURFACE 9 5/8 8.765 37.0 4,797.5 3,635.1 36.00 J-55 B TC Casting Description String 0... String ID...Top(ftK6) Set Depth(f...Set Depth(TVD) .String Wt...String._String Top Thrd WINDOW'A' 8 6.500 4,872.0 4,882.0 3,681.4 Cuing Description String 0... String ID...Top OMB) Set Depth(f...Set Depth(TVD). String Wt...String...String Top Thrd PRODUCTION-post 7 6.151 36.8 5,000.0 3,751.5 26.00 J-55 BTC Sidetrack Cuing Description String 0... String ID...Top(MB) Set Depth(L..Set Depth(TVD)...Sting Wt...String...String Top Thrd -_ ;a�aw LINER 3112 2.992_.4,665.8 8,190.0 9.30 L-80 IBT-Mod II Liner befalls Top Depth (TVD) Top net Nomi... Top(RKB) MKS) r) Item D won Commend ID On) CONDUCTOR. _-- 37-115 4,665.8 3,561.5 56.06 PACKER BAKER C-2 ZXP UNER TOP PACKER 5.250 4,686.1 3,572.8 56.09 HANGER BAKER FLEXLOCK UNER HANGER 4.400 III 4,695.9 3,577.9 55.77 PBR SBE ---___ 2.950 4,716.2 3,589.4 55.80 XO BUSHING CROSSOVER BUSHING 2.992 SAFETY VLV, 2,103 ,. 4,725.0 3,594.3 55.81 NIPPLE HES'X'NIPPLE 2.813 8,156.8 6,453.6 42.97 COLLAR BAKER LANDING COLLAR 2.950 4 8,159.2 6,455.4 42.97 COLLAR 2.992 I. Tubing Tubing c Description !String 0... (String ID (Top(9KB) 'Set Depth(f...1 Set Depth(TVD) String Wt...SUmg_ String Top Thrd TUBING 3 GAS LIFT, Completion Details npl2 2992 ll 233 4,717.4 3,590.1 9.30— L80 EUESrdABMoOD 3,034 Top I /ND)I Top(ftK6) (91(B) (1 nemD Description__.. Comment ID(in) 23.3 23.3 -0.01 HANGER FMC 3-1/2"Gen IV Tubing Hanger 3.500 2,102.6 1,991.7 39.01 SAFETY VLV CAMCO TRMAXX-CMT SCSSV w/2.813"X profile 2.812 4,679.9 3,569.4 56 OS LOCATOR Locator NO GO 2.992 4,695.8 3,577.9 55 77 SEAL ASSY Baker 80-40 Bonded Seal Assembly 2.890 F.. -__ ,'asp.5 ,e , -,ay n GAS 4L155 - Notes:General&Safety -__ ,n-x ,, ,� -.,,.2,1 End Date Annotation 7/3/2010 NOTE:WELL SIDETRACKED&NEW TUBING COMPETION SET,PRE-CTD MULTI-LAT DRILL I 7/14/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 7/14/2010 NOTE:""TUBING COMPLETION DEPTHS NOT CONFIRMED II LOCATOR, 4,680 1 11 I SEAL ASSY, 4,696 Ir I I j I ;_ /: t. SURFACE,-_ • 37.4,797 WINDOW'A', 4,8724,882 Mandrel Details .- Top Depth Top Port PRODUCTION (TVD) Inc/ OD Valve Latch Size TRO Run -posy Sidenudi,--_.. Stn Top(MKB)_..(ftK6) (') Make Model (In) Sne TA. TA. (In) (Psi) Run Date i Corn... 37-5,000 1 3,033.6 2,607.2 52.22 CAMCO KBG-2-9 1 GAS LIFT DMY BK-5 0.000 0.0 5/30/2010 2 4,593.7 3,521.2 55.95 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/11/2010 i LINER, 4,666-8,190 7D(3N-16A), V_ OR\ G\NL g 3 i,9, O 0 0 2 2 � C▪D N 2 M a0 ic m in Q �`CO QI QN �� 0 O l0 3Vano 0C+ r a r a0 r a0 0 N M O Q N r C•1'8 O d N J N O C N J Q m a m Q m j Q J CO O. J m 0 n o g axh 2 co v co- j @U to c_ N co m DO E � . O C C V in zo CI m E co g E v a`,ro of ii: an o�rn 0 2 mY O g V E E l0 N U U m t a x x d X \ • • N Y m fV N N AIM a+1 C'S CO' m2 A MMM M I i V CCS L `! X11 Q / �+ .A�` -0 ________\ CD o co O I m L 0 C I y O O n an Q 0�0 �-- co Q O in 0 0_Y Z:..1 8 in 0 O CO n Z to 0 0 Y m vi fn C7 ° r flotniNIA. 1 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-16 3N-16AL1 Plan: 3N-16AL1 wp04 Standard Planning Report 06 August, 2010 BAKER HUGHES ORIGINAL ConocoPhillips VIM ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-16 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 3N-16A @ 60.28ft(D16(34.1+26.18)) • Site: Kuparuk 3N Pad North Reference: True Well: 3N-16 Survey Calculation Method: Minimum Curvature Wellbore: 3N-16AL1 Design: 3N-16AL1_wp04 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 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14° Well 3N-16 Well Position +N/-S 0.00 ft Northing: 6,013,799.25 ft • Latitude: 70°26'55.947 N +E/-W 0.00 ft Easting: 518,370.74 ft - Longitude: 149°51'0.470 W 'Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.10ft , Wellbore 3N-16AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) r) (nT) BGGM2009 9/15/2010 17.04 79.88 57,401 Design 3N-16AL1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,122.54 Vertical Section: Depth From(TVD) +W-S +E/-W Direction (ft) (ft) (ft) r) -34.10 0.00 0.00 37.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/1OOft) (°/100ft) (1100ft) (°) Target 8,122.54 42.97 92.76 6,368.28 -2,130.12 3,345.33 0.00 0.00 0.00 0.00 8,170.00 • 42.97 92.76 6,403.01 -2,131.68 3,377.65 0.00 0.00 0.00 0.00 8,250.00 78.61 98.74 6,441.44 -2,139.20 3,445.90 45.00 44.56 7.47 10.00 8,330.00 88.84 63.96 6,450.45 -2,127.20 3,523.14 45.00 12.78 -43.48 284.00 8,365.00 90.11 58.86 6,450.77 -2,110.45 3,553.86 15.00 3.64 -14.55 284.00 8,390.00 91.02 55.22 6,450.53 -2,096.86 3,574.84 15.00 3.63 -14.56 284.00 8,625.00 91.29 19.97 6,445.64 -1,913.62 3,715.92 15.00 0.12 -15.00 270.80 8,705.00 95.34 31.28 6,441.00 -1,841.73 3,750.38 15.00 5.07 14.15 70.00 8,785.00 93.16 43.12 6,435.05 -1,778.31 3,798.54 15.00 -2.73 14.79 100.00 9,005.00 90.48 76.03 6,427.86 -1,668.52 3,985.55 15.00 -1.22 14.96 94.00 9,200.00 89.93 105.27 6,427.16 -1,670.71 4,178.42 15.00 -0.28 15.00 91.00 9,290.00 89.35 118.76 6,427.73 -1,704.37 4,261.66 15.00 -0.65 14.99 92.50 9,393.00 89.37 103.31 6,428.90 -1,741.22 4,357.50 15.00 0.02 -15.00 270.00 9,433.00 88.03 97.46 6,429.81 -1,748.43 4,396.82 15.00 -3.36 -14.62 257.00 9,593.00 - 88.20 121.47 6,435.16• -1,801.33 4,546.49 15.00 0.11 15.01 90.00 8/6/2010 10:16:11AM Page 2 COMPASS 2003.16 Build 69 L I\ WM -- ConocoPhillips FA kl ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-16 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-16A @ 60.28ft(D16(34.1+26.18)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-16 Survey Calculation Method: Minimum Curvature Wellbore: 3N-16AL1 Design: 3 N-16A L 1_wp 04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Fasting (ft) (°) (°) (ft) (g) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,122.54 42.97 92.76 6,368.28 -2,130.12 3,345.33 312.08 0.00 0.00 6,011,677.59 521,720.98 TIP 8,170.00 42.97 92.76 6,403.01 -2,131.68 3,377.65 330.28 0.00 0.00 6,011,676.11 521,753.291 KOP 8,200.00 56.30 95.55 6,422.39 -2,133.39 3,400.39 342.60 45.00 10.00 6,011,674.46 521,776.03 8,250.00 78.61 98.74 6,441.44 -2,139.20 3,445.90 365.35 45.00 8.18 6,011,668.76 521,821.56 3 8,300.00 84.74 76.84 6,448.76 -2,137.23 3,495.00 396.47 45.00 -76.00 6,011,670.85 521,870.64 8,330.00 88.84 63.96 6,450.45 -2,127.20 3,523.14 421.43 45.00 -72.79 6,011,680.95 521,898.77 End of DLS 45 8,365.00 90.11 58.86 6,450.77 -2,110.45 3,553.86 453.29 15.00 -76.00 6,011,697.77 521,929.44 5 8,390.00 91.02 55.22 6,450.53 -2,096.86 3,574.84 476.77 15.00 -76.00 6,011,711.42 521,950.38 6 j 8,400.00 91.04 53.72 6,450.35 -2,091.05 3,582.97 486.30 15.00 -89.20 6,011,717.25 521,958.50 8,500.00 91.20 38.72 6,448.39 -2,022.07 3,654.96 584.71 15.00 -89.23 6,011,786.40 522,030.30 8,600.00 91.28 23.72 6,446.20 -1,936.82 3,706.63 683.89 15.00 -89.52 6,011,871.77 522,081.76 8,625.00 91.29 19.97 6,445.64 -1,913.62 3,715.92 708.01 15.00 -89.85 6,011,894.98 522,091.00 7 8,700.00 95.10 30.57 6,441.45 -1,846.01 3,747.83 781.21 15.00 70.00 6,011,962.67 522,122.73 8,705.00 95.34 31.28 6,441.00 -1,841.73 3,750.38 786.16 15.00 70.59 6,011,966.95 522,125.281 8 8,785.00 93.16 43.12 6,435.05 -1,778.31 3,798.54 865.79 15.00 100.00 6,012,030.48 522,173.27 9 8,800.00 93.00 45.36 6,434.24 -1,767.58 3,808.99 880.65 15.00 94.00 6,012,041.24 522,183.691 8,900.00 91.83 60.33 6,430.00 -1,707.42 3,888.39 976.49 15.00 94.12 6,012,101.59 522,262.94'. 9,000.00 90.54 75.28 6,427.91 -1,669.76 3,980.70 1,062.11 15.00 94.76 6,012,139.47 522,355.15 9,005.00 90.48 76.03 6,427.86 -1,668.52 3,985.55 1,066.02 15.00 95.07 6,012,140.72 522,359.99 10 9,100.00 90.22 90.27 6,427.29 -1,657.22 4,079.62 1,131.66 15.00 91.00 6,012,152.25 522,454.03 9,200.00 89.93 105.27 6,427.16 -1,670.71 4,178.42 1,180.35 15.00 91.09 6,012,139.01 522,552.85 11 9,290.00 89.35 118.76 6,427.73 -1,704.37 4,261.66 1,203.56 15.00 92.50 6,012,105.56 522,636.17 12 9,300.00 89.35 117.26 6,427.85 -1,709.06 4,270.49 1,205.13 15.00 -90.00 6,012,100.89 522,645.01 9,393.00 89.37 103.31 6,428.90 -1,741.22 4,357.50 1,231.81 15.00 -89.98 6,012,068.95 522,732.091, 13 9,400.00 89.13 102.29 6,428.99 -1,742.77 4,364.33 1,234.68 15.00 -103.00 6,012,067.41 522,738.92 9,433.00 88.03 97.46 6,429.81 -1,748.43 4,396.82 1,249.72 15.00 -102.99 6,012,061.84 522,771.42 14 9,500.00 88.06 107.52 6,432.10 -1,762.89 4,462.11 1,277.46 15.00 90.00 6,012,047.54 522,836.74 9,593.00 88.20 121.47 6,435.16 . -1,801.33 4,546.49 1,297.54 15.00 89.66 6,012,009.31 522,921.20 TD 8/6/2010 10.16:11AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL , . ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-16 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-16A @ 60.28ft(D16(34.1+26.18)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-16 Survey Calculation Method: Minimum Curvature Welibore: 3N-16AL1 Design: 3N-16AL1_wp04 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name f7 (") 4,789.28 9 5/8" 9-5/8 12-1/4 4,882.00 7"TOW 7 8-1/2 9,593.00 6,435.16 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,122.54 6,368.28 -2,130.12 3,345.33 TIP 8,170.00 6,403.01 -2,131.68 3,377.65 KOP 8,250.00 6,441.44 -2,139.20 3,445.90 3 8,330.00 6,450.45 -2,127.20 3,523.14 End of DLS 45 8,365.00 6,450.77 -2,110.45 3,553.86 5 8,390.00 6,450.53 -2,096.86 3,574.84 6 8,625.00 6,445.64 -1,913.62 3,715.92 7 8,705.00 6,441.00 -1,841.73 3,750.38 8 8,785.00 6,435.05 -1,778.31 3,798.54 9 9,005.00 6,427.86 -1,668.52 3,985.55 10 9,200.00 6,427.16 -1,670.71 4,178.42 11 9,290.00 6,427.73 -1,704.37 4,261.66 12 9,393.00 6,428.90 -1,741.22 4,357.50 13 9,433.00 6,429.81 -1,748.43 4,396.82 14 9,593.00 6,435.16 -1,801.33 4,546.49 TD 8/6/2010 10:16:11AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL V) 0 vs W . . . . . 8 s �o ° si , ^ — 8 ° Z er o S ^ 8 a CD kn $s2 v .00 _ �.. o� `M m if m s N z o &&&ate „ 3 7 ^ U�UM � p ° ro . . 8 . . z N e p N + _ O .0 _ .o_z .0 _0 __- o Q 0 ■ ' W °o 6 kel `/ J • 0 O Ko 8 _.. 8 8 8 $---8 8 8 E 8 8 8 & 8 .. ----8 M 14 74-9 I (u►/8 001)(+)4poI�J(-)gnoS o IyZ� a o U !I b ti Z r 0 1,gi Z i - r ° a0 °G o.-<v coed _ 0 6 H Y 1+)W.CO 1�.. 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If/hit_1 Z O IN1f! 4 P110, - §. zv. ,� e.c "' 8 to t Y Y j 3.2.--A .: & 42A.4-i Iiiii s 8• J N' N 7 es o i 8 00 'V G en N a. / - g F, 0 0 0 0 t o d o g 8 o g § _ _ o g o g o $ o Q _g Q [r ... O N P N r O 3 1� (Ulj oci) (+)L °w(-)41nos N o 40••§ N 0 0 I ‘,.., ORIGINAL TRANSMITTAL LETTER CHECKLIST• WELL NAME • Tl I PTD# ?1 C-' 1t' 7 Development V Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: V C-(1. 6--c-) ( 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 segme t of existing well -54/—/6a (If last two digits in Permit No. 2/b l S 3 I API number are ��l ,API No. 50-ZjZ - Z 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 N 1 ! T N _N 2 ❑ O a m a) 7 ii ci w (n p a) C L a 0) u) co C m 0 CO 0 N C N 0 co 5 13 Vi a d -g o -5 co 0 c O O_ N o) V. L E a) N N N E‘2 O ❑_1 cn N 0 m 7 O a To V) = 3 °) Q U L E z E n 0 6- m a Q O • W U' 1) a) • o 0, Z •-° a3) c z h rn '3 a E 3 U) c° m 0 3 co m ° o - 7 ai o f > > Y U 0) 'C 5 O C 0 CO N 1- @ a ^ N U ❑ n 0) J ❑ "0 @ U. Vi n ,-- n W 7 - o @ c a U a) o , • ui N _ 09. 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