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Home My WebLink About202-223 aoa - as Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 sIUN 0'2018 Phone: 907/777-8547 SCOW) June 5, 2018 RECEIVED Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission JUN 06 2018 333 West '7th Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Conductor Annulus Corrosion Inhibitor Treatments 4/20/18-5/12/18 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of wells that were treated with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease-like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, PTD and API numbers, treatment volumes and treatment dates. This treatment campaign represents primarily new Milne Point HAK drill wells along with two Northstar wells which previously had excavations and external surface casing leak repairs. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC • Cl) CO CD CD CUCDU) CUQ) a) a) a) Cl) U) c c c c c c c c c c c c C J J J J J J J J J J J J J O O Q L C C c C C C C C L C C C ; , O OOOoOOO on U U a) a) a) a) a) a) a) a) a) a) a) a) a) Q r C Q 0 C O C cCeC cecect C C • c c C c cc c c c c c cc L C a) a) a) a) a) a) a) a) a) a) a) a) a) o 0 LE E E E E E E E E E E E E E U U a) m a) (1) a) a) a) a) a) a) a) a) a) U U U U U U U U U U U U U 73 Q Q Q Q Q Q Q Q Q Q Q Q Q oo C Q Q II CU C co it a> O Or O a a a La U) I U) U LU O ) U) Er r r r N N 0 O O r r N O U o :2 O c = CO CO a0 CO CO CO CO CO 00 CO CO a0 co CO CO r r r r r r r _ r r O *w N N N N N N N N N N N N O N N ✓ C O O ( N N N N C) C) r) M N N 01:1 i N N N N N N N N N N N N O U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LU Cr) r 0) CO f— CO O 0) N V' M 0 N r LU U) CO M U) U) M N O) co U) N O I- cc) r O r O r r O N C a CO CD CO CO CO CD Lf) LU O LU LU LU f- N N C r O O Q N N NNNNNNNNNNNNN O U O a a 0 0 0 0 0 a 0 a 0 (D0 0 C O 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 O (� O O O O O O O O O O O O O O O A co - r O co 0) ti CO f` N LO LU O CO CO CO CO f— f- f— CD O O CO LU - U) CO ti N Q. 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Barnes MAR n i 7ntR Senior Vice President and North Slope Asset Team Leader Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 `'°' Anchorage, Alaska 99503 Dear Mr. Barnes: sameL.r,' During the inspection out-briefing at Northstar Production Island on July 20, 2017,Hilcorp Alaska, LLC (HAK), requested clarification concerning our approach to the inspections of federal wells at Northstar. This topic has come up in various meetings with HAK in recent years. Therefore, this letter provides updated guidance to HAK regarding how we will approach inspections related to the federal wells at Northstar. Our goal here is to provide better clarity for HAK by setting down in writing what we have been relating verbally to HAK since you took over as operator of Northstar in 2014, and by drawing clear distinctions around our inspection parameters where it is practical for us to do so. Please be advised that this letter explicitly supersedes the February 1, 2005 letter from this office to BP Exploration Alaska, Inc. (Jeffrey Walker to Gray Herring). BSEE will conduct inspections related to all North Star federal wells (currently including NS-6, NS-9,NS-12,NS-22,NS-30,NS-32, and NS-34A) according to the following. The federal wells are subject to applicable federal regulations from bottom hole through Safety and Pollution Prevention Equipment(SPPE) and any devices that protect the wellhead. SPPE and devices that protect the wellhead will be generally defined as, but may not be limited to: a. Subsurface Safety Valve (SSSV) and their control system/actuators to include any component in the process stream establishing set points. b. Surface Safety Valve (SSV) and related actuators(e.g. a Pressure Safety High/Low, or PSHL)to include components establishing set points such as: tubing and annular pressures (static and flowing), first flowline segment pressure ratings, and first stage separator vessel pressure ratings. c. Injection Valve. d. Tubing/annular subsurface and surface safety devices. e. Emergency Shut Down (ESD) system and related controls. f. Any Temperature Safety Elements (TSE), Temperature Safety High (TSH) or other heat/fire detector installed at the well related to the actuation of well safety devices. g. Wellhead Injection Lines and Gas Lift Wellhead Injection Lines and related safety devices to include: Pressure Safety Valves (PSV), Flow Safety Valve(FSV), and PSHL. • w This letter sets forth the current BSEE regional policy for conducting federal well inspections at Northstar; however it does not represent a binding statement on the extent of BSEE's jurisdiction over facilities in state waters with wells that reach the OCS. If you have any questions about this guidance please contact Michael Jordan at michael.jordan@bsee.gov or at(907) 334-5300, Sincer ly, Kevin J. Pendergast, PE PG Regional Supervisor, Field Operations cc: James Regg, Inspections Supervisor, AOGCC STATE OF ALASKA • AOKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ roduction Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Othe . Repair Surface Casing 2. Name: 4.Well Class Before Work: 5.Permit to Drill Numl?r Hilcorp Alaska LLC Development 0 Exploratory❑ 202-223 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23128-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: OCS Y-0181 NORTHSTAR UNIT NS-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): RECEIVED N/A Northstar Field/Northstar Oil JUN 0 9 2016 11.Present Well Condition Summary: Total Depth measured 12,887 feet Plugs measured N/A fOGCC true vertical 11,141 feet Junk measured N/A feet 10,458, 12,257& Effective Depth measured 12,860 feet Packer measured 12,307 feet 9,293, 10,664& true vertical 11,121 feet true vertical 10,702 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED JAN lj n17 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13Cr80/Vam-Ace 12,303' 10,699' 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2" 10,458MD/9,293TVD, Bkr Lnr Top Pkr&7" 12,257MD/10,664TVD, Packers and SSSV(type,measured and true vertical depth) x 5"Bkr ZXP Pk 3-1/2"TRM-4E SSSV 12,307MD/10,702TVD 1,142MD/1,127TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 860 46,018 190 7 796 Subsequent to operation: 843 44,399 28 86 792 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316x1.64" 2,yC Contact Taylor Wellman -rrtd Email twellmanhilcorp.com Printed Name Mike Dunn Title Operations Manager ce/ Signature Phone 777-8382 Date 6/9/2016 Form 10-404 Revised 5/2015 7 6•Z i"llc RBDMS JUN 1 0 2016 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-22 N/A 50-029-23128-00-00 202-223 5/3/16 5/14/16 -Daily Operations: ' 5/3/2016-Tuesday Completed the excavation around NS-22 with the on island camel vac so we are ready to simply place the trench box around NS-22 upon the flowline removal. In addition we got approval to use the existing CMP cellar from a PE as our trench shoring from -8'to the-16'. We only used the Peak super sucker for one day and we did use LRS at all. The gravel is able to be vaced up easliy nor are we encountering water. There was confirmation testing conducted on gravel to insure no comntamination. 5/4/2016-Wednesday ATP was complete and SL RU on NS-22. PT to 300psi low/4000psi high. Drift and brush nipple at 12,295' md.Set the plug at 12,295' and at approximately 6:00 PM. The Evo Trieve tech and plug are on standby in case tge plug does not hold.The night maintennace crew bled down the T/I/O to 0 psi and safed out the well for the day crew. Notified State of conductor cutting scheduled for Friday(48 hr notice) 5/5/2016-Thursday o 7:30—9:30 HAK techs removed heat trace, hydraulic tubing,flow line etc.We were able to swing the flowline out of the way. GBR welders arrived onsite and completed SEMS and island orientation. Set up crane for lifting trench box and lifting floor/cellar pieces. ATP (1:00-3:00)with incoming crew completed. GBR started cutting the cellar out around 3:30, completed at 10:00 PM. We had allocated nearly 12 hrs. but working with the crane hands and the welders and due to the Maint crew removing 2 small risers we were able to remove the cellar and the floor together and safely. Fire watch was utilized.Parachuted and ran heat all night to facilitate easier excavation tomorrow morning 5/6/2016-Friday Finished excavation and installed 2 steel plates (4'x5'x3/8") between the outside of the front trench box and the outer cuter edge of the CMP in accordance to the trench shoring plan. These plates will inhibit any gravel material from sluffing between the 2 boxes. Shut in at the surface NS-21 and 23 prior lifting trench boxes into place (downtime was ):16 minutes on NS-23 and 20 minutes on NS-21. Place one 10'W x 10' L x 4'tall trench box around NS-22o Bring NS-21 and NS-23 back on line. Continued to excavate inside of culvert cellar(2-3 hrs.). Install secondary containment at base of conductor to collect any fluids expelled during drilling of holes in conductor. Drilled 8 holes total and no fluids were seen. Tested LEL's with a 4 way gas detector placed at each hole. Team discussed the use of the carbon air arc gouging for the cutting of the conductor and agreed that it was the best approach. Taylor attained approval from BSEE and AOGCC(in writing)that the alternate cutting method could be used. Mike D was updated via a phone call and also approved. Secured the braden head and the future conductor pup with a chain and binding system. The State inspector(Bob Noble) arrived on site for the cutting of the conductor at approximately 2:30 PM via hovercraft. The cutting of the window was laid out approximately 6" below steel cellar floor and down 3' down.The cutting of the conductor and then finishing with the grinders started at 3:00 PM and was finished at 6:00 PM. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-22 N/A 50-029-23128-00-00 202-223 5/3/16 5/14/16 Daily Operations: 5/7/2016-Saturday Conducted pressure test to locate the leak- Initially put water in the bottom of the conductor so we could see if any N came from below. Put soapy water on lip of the collar. Pressured up to 80 PSI, could hear the leak but no indication at collar so dropped the pressure off. Installed flagging below epoxied area and soapy water on top of the epoxy(see pic). Pressured up again to 50 lbs. and the flags at the 7:00 position indicated an obvious gas flow and no bubbles coming from the top of the epoxy. Concluded that the hole was just below the epoxy at approximately the steel cellar floor location. Consulted Taylor via phone and discussed as a team to insure we are addressing all issues for well stability etc. Drilled holes from the bottom up thru the epoxy to hopefully weaken the Well Lock epoxy shear strength between the casing and the conductor.The crane will be hooked to the crane to steady the well head due to the corrosion. Once the conductor"ring" is removed we will buff the Well Lock until we locate the exact location of the leak/corrosion. The holes were located and the State Inspector Bob Noble was notified via phone by Konrad at approximately 2:00 PM. He requested a brief description of the repair/layout be discussed with the AOGCC engineer by HAK engineer. Conducted UT test on the entire exposed casing to identify competent areas for the bands. Working with welders to maximize the area for access and layout. GBR prepping rings and will do fit up tonight. GBR/Welding to commence tomorrow morning due to the pre-heat and the then the cool down. Layout to be updated after UT. UT complete at approximately 10:00 PM. 5/8/2016-Sunday The layout and the fit up of the 4" rings was completed. Welding commenced with the WTI present. Upon completeio of both 4" wide rings being welded they were wrapped in insultation to allow the slow cooling of the welds. MT and UT/shear wave tests scheduled for first thing in the morning. 5/9/2016- Monday Testing of welds on both collars is complete and all welds passed (pics of rings below—top and bottom). Test results will be placed in the well/Project file upon completion.Welders prepping cellar while testing was done and prep/weld 5' clamshells on to rings —10-11 hours of welding. 5/10/2016-Tuesday UT/MT and shear tests conducted and all passed. 10:00 AM MIT witnessed by State inspector(Bob Noble)to 1,000 psi. Upon completion welding on the conductor was started and completed. No testing required on the conductor. 5/11/2016-Wednesday GBR fitted up and welded conductor sleeves. CMP backfilled to steel cellar floor elevation. Plan for trench box removal approved by Kasey Bond HAK safety.Shut in NS 21 and 23, remove 4'trench box.Bring wells back on line, approximate shut in time 20min. Began backfilling and pulling front trench box in lifts compacting with plate compactor. Remove trench box upon reaching steel cellar floor elevation. Continue backfilling and compacting till proper grade reached on all three sides in front of CMP. 5/12/2016-Thursday Place and weld up steel containmnet cellar/containment basin 5/13/2016- Friday Flowlines and instruments reconnected to well. SL set up on well 5/14/2016-Saturday SL RU and PT to 300psi low/4000psi high. Pull prong and plug from 12,295' md. RDMO. • • Northstar NS-22 CasingRepairProject Project Summary Scope of Work Excavate around and directly in front of NS-22 to a depth of—12 in order to cut away cellar and conductor pipe to repair casing leak at an approximate depth of 4'. Timeline Pre-Job 4/14/16 NS-22 failed MIT-OA after attempt was made to repair casing leak with WellLock. Decision made to execute excavation of well to repair casing with two half shell patches and rings. HAK began materials procurement, and continued plan preparation for submittal to appropriate agencies. 4/18/16 Begin holding daily planning meetings with HAK Operations engineers, island personnel, safety and environmental and contractors directly involved with project. Partial list of topics covered • High level overview of plan • Options for execution of plan • Materials procurement • Logistics • Personnel requirements and duties • Safety and Environmental concerns • Procedures required for welding • Contingency planning Field Work Timeline 4/29/16—Excavation started 5/4/16—plug set in well and well secured 5/4-10/16—leak located, UT on casing(entire area), rings welded, clamshells welded 5/10-16—State witnessed MIT completed to 1,000 psi 5/10-11/16—Conductor welded 5/12-14/16—backfilling, cellar installed, flowlines reconnected 5/14/16—Well brought back onto production • • A o 1 ' Mik.',..,""e7:It.F.i".- -i .'.a • t .a ^ aid, fc „, 1 ,, :,,,,,, ,,,cr.;:tf.:,fIti.r. .:.,'Alk,,71#.4 s ! ,rt 1r ate" , „ Pit,-x2$' , ji., .ht4,47#4,.''' . '' 1 ::, g I li 1 ,. ,. 4 ..1 '. ;y illailw _ ".fir 7i � -,i. �.. to '4,VAVit-,104,1*:'...*,:',.f.*'-,-;',.r*,''-,-'4".t,."-°.4.,..,',., . . - „A' /- .,-°,,4i... .f ,;••,:iit.',.'..",.."..-..• <..-- . ',.,.. , -"-..'.''%.,...,,,-;,...,a..,:.,,,,.." ' Ito ' .0-,,,i-,c., h S • ,, t Mw„ '✓,4 i v`i'a ".t'd a v i �}iP`cti s " ., .an . ` 1Td +� • '4, r V. as "' Orange paint line denotes closest acceptable point of excavation by excavator to flowing well. f all) "" ♦. s. d x. ft — ` ' e" " � '1` � x � "'� ,,,,...4 , ' - -,---,..A�A. • • .. I g i }} aR L .c,' f 11.1 1 l ,,,,I / eel"' I 0 } l so ,tgl.:„.,, }-[ '+ ,--Waw`. ''',6-1;,-..4 �` gyres � ati� s4--- .w— , .� 76. e . pt.. . - 1„, 1 .0'..i, , ...... *:- .:. » ii,. to TIF '1 'z'.-\ �,z �•� Ij. ..4 r oitT, x„x ct r k :+i * i '_x [ r r w: rotr m ! rg q ,y ....xt`" ix.1„,,,,,,,,,,......1 •- p!u � p,.,q s?E2 ' �.. \`r 4-.i , • e ” , ', f ark-- �'"' ? h 4 ry s , r c -;,..4,- 4 4 v Aa,,.4d a, a .,sA.,m -...,...'......-...-,.......-7.,,,z0,:.:, v:S'"'3=`�c '' wa„,,... ...,,,,,,y,,, ,,,,,-,...i...,,,,'* r ,45 :*'' '` �4';'”S�i"'`✓.1'^a?tom '.' r;k "� 7 �.< .1 .tr *.4,, , * ,,t,-:,,, e°^a. a a.,`` >, '> Cellar was cut in two pieces,front piece rigged for removal i S . tAtqlt.0411poit Sy " '‘',1 2 Ski�� sa •'PI • 4 Removing front half of cellar • • '''''r ' - ' iiii"r1,11111/17\ i fi n illii:."..-1 .4 dd w s,. - gni 0 I f r , ':-. .,,ii.;, ,,,,,,r, . ,, A L.,. ,. .. ..,..4. ,.. . . ,,,„,,. , ,.. _ __ , _-4,-...„ , � A - .,rte e 4.,,,,,L,... ,,,,,,,f,„4„,- .. c..;;;5° x ,..... . . , • 4.„.. a , ‘T.' - Oi "Cir 4 ate . , � � .- rr , \goloosiv. i' y3'}' ., 4 FV , • lii ,, L:, . x RF y,� 'yp € -4. a r ri'IR m3f. v a.. 4y 'i t � LAW' '' .. 2*„ Back half of cellar laid out for cutting • • i 2.T 133 v 3., I '''-, 'r3a*"-::- 1 „ o- _.„ cc," t, .'III ""' ' 11'''1411t, ..',,,,m,„,,,,,..-:,* y ti ° yid ......w—a {I 0 } u 4 .., 1 y aye . . 0 • a ww Ate , t 400614611011164 Kk +�" �" ,e " o° ens x001011111,40, AO , 1e + , y 0 .tir lir , Conductor removed. Old cement removed and surface casing cleaned. Lower Right—Leak site unidentified,testing to identify location. i 0 e s � w - w . ' �� ,� `"?A moi.� , x . -w. „- a '« ` wa , ,c i. • it r' f ,:,,, . r a $ ,$.44 roe* °, ltrk y � "` � i ";" �� *'max. t _ -; , ' r , h -':‘ - ft; "!....;7::'$$'-';',1*•'.:i'''';',.' ',$$$004t, r z e �: ,, ., M 1/4 oles in Leak site. 3 h ^2" square. i i PG ��Image KB y. ,-441110140 n: 640 x 480 pixels � .- "AV"' -. * Alp( -::!. 74*...."*%*"*. f''''' '':'''' ; ' *;. } �' � k,;* 'R1 V ".1. . ' Upper and lower patch rings welded in place. • • sartu5' a. t. .6, A _ "fie , i !/ 1 s 1 , x 5 ¢ 0 — s w c. , — ,,, i t 3 'v,'', 1 4p ',^ ° s ,,,r4e v,,,,, 'it''''' ''''. ' r :*ir Aow, :1,,,...!,.....„.., . .......--„,,,,...1., ,.. ate. Patch fully welded to surface casing. • • y t4-.` w T J '0 l W M` H 111141/4 T F ,�. � �Y _ 4 r O: f m y .. , Fitting up conductor clamshells i ,„p kms s"a b € Vie. 3 >, Feu iaS �, ,x ,�,..-�.». ,,.,� k �° as . ..a �" ::...sem " d+4t jp, ,, �a t " F: Conductor shells welded in place • • �iA� it::-t .„,r.„..,,,,,..,.. • lia::1::i.:7'14,' i ^. 11/if i - ..2.'1..;4"....:::,,1:::.„ S yyjit) �Y 4� , ,..:„: .......„,..:„..:.. . .,,, .., . •• -,11' r „, ' :; s ....,,-. 7,,. _.11,,,,,,,,,,•:-.:'„,x,,.........„.::-.J.,,!..,-...::,„,. ..„:1;:i.: :.,!,,,;•,,,i,'--...!:„:-.,..----..,.. ...:7; ..,...,:.,,„...,,,,,,:, Ei. e t a .� - 1 - ii :'> ' ,.M."M may.'4 . "yr:'. • a;`sem _ • . ,t,gy•y,r ' s -ry, s µ 3,, e •,yr " y .ms � • MSk w *rt. S« W. Si-, "�,, s4 `�'y „,..-.5,1j'..":""....-4,;,.;%': -" iMAA+. * y+" `Sd a '' -,-.� + ., # w +,"- .+, - � - a +.. •" ;: �ar �b ' ay t �a "3}'. az�a.+ ; � +Vic4k1' mar! • •-..,..-,'-*°:,:,..-',:',..-,4-.74-7 x ', ''': .,:..'••••:''' ' • : 4 :. Trench boxes removed ready for cellar reinstall • • "-'. ate-., . ,.. . '1',1.., , ,fir.,17,1 i . ,. I t 1JJ !7 — — I ----- Wi=•t ce• f0 .. C >.i 9 y � �� war, mss; , ry yp _s- �'b. la 1pj, �dam. d x /,'' _ , « t. .W..} :F' , T -- - r yf _,--- .y... ,v >-t 0 1077 .k. Backfilling cellar • • '•.„,-,,,.:.:-.,:', 7,' .. ',, 1 , , ; , „ fr , €c, _ 111,::.,, i x ,__ 1 ' „„-. .: v_ di, , y" \I „„/ �� iti a► lC -.Z7' u ` as«c _ 4 t _ .M ttr t •R ',. ''.:-'s,,.' ' d ate'' ate + +„crr�," * 2 "` �y *-.',':.3,1g,. , rw '" {..r ,,`' ^? :".4;-,,,t.1:'74-.,..,.-$,...°!:...,,-.... "'".',,t,-'7-.. .,,---.::-... :731.4'4.4.7.4,7.1:--- "' ';� 'war x ti y f z4 ® 41- @ .: c •�. ... Finished back fill • • Conclusion In planning this project assumptions were made and contingencies put in place to deal with the variables that may have been encountered. Many of our worst case scenarios were not realized on NS-22. Below is a partial list along with some additional lessons learned. • Frozen ground necessitating the use of hot water, steam or air knife-Ground around NS-22 was easily thawed where frozen. It would be reasonable to expect similar conditions on NS-15. Endicott 2-60 however may show more signs of compaction. • Water in excavation—No water was encountered at NS-22. Leak was estimated at^'4' below OA valve.When located, leak was at 42" below OA valve estimates of depth were fairly accurate. Endicott 2-60 estimated depth is 11.5' below OA valve and NS-15 is 10'. Dewatering plans should still be in place for these wells as with the deeper excavation required water cannot be ruled out. • Contaminated gravel—Containment was constructed in the event contaminated gravel was discovered. Sampling plan was in place.Anytime these wells are dug the possibility exists for old spills to be discovered. Same plans with containment should be used on future well excavations. • Welding—Many ideas came directly from the welders completing the task. Future planning should include the welders performing work to perform site visits for input. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocaalaska.gov: doa.aoocc.prudhoe.bavaalaska.gov: phoebe.brooks[7a alaska.gov; chris.wallaceAalaska.gov OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Northstar/NSU/NS DATE: 05/10/16 OPERATOR REP: Vann Betzel AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NS-22 Type Inj. N TVD 12,377' Tubing 0 0 0 0 Interval 0 P.T.D. 2022230 Type test P Test psi 1000 Casing 0 0 0 0 P/F F Notes: Diagnostic MIT to 1000 psi following SC leak repair. OA 0 1180 1080 1010 Well NS-22 Type Inj. N TVD 12,377' Tubing 0 0 0 0 0 Interval p P.T.D. 2022230 Type test P Test psi 1000 Casing 0 0 0 0 0 P/F P Notes: Diagnostic MIT to 1000 psi following SC leak repair. OA 1050 1240 1180 1140 1120 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT NSU NS-22 05-10-16.xls • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Wednesday,May 11,2016 P.1.Supervisor ( 1 qq 51 lice SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC NS-22 FROM: Bob Noble NORTHSTAR UNIT NS-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jT NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-22 API Well Number 50-029-23128-00-00 Inspector Name: Bob Noble Permit Number: 202-223-0 Inspection Date: 5/10/2016 Insp Num: mitRCN160510140837 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r T - Ns-22 Type Ind N i1TVD 12377 Tubing o 0 0 , 0 1 PTD L 2022230 Type Test'I SPT'Test psi 3094.25 IA11 0 0 0 0 Interval LOTHER P/F 1 F V1 OA 0 1180 . 1080 - 1010 • Notes: First attempt to pressure test OA on NS-22 surface casing repair.MIT-OA to 1000 psi as per Sundry 316-246. SCOW SEP 2 7 2016 Wednesday,May 11,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '7I 1 DATE: Wednesday,May 11,2016 P.I.Supervisor (\ 51i);-//ca, SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC NS-22 FROM: Bob Noble NORTHSTAR UNIT NS-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-22 API Well Number 50-029-23128-00-00 Inspector Name: Bob Noble Permit Number: 202-223-0 Inspection Date: 5/10/2016 Insp Num: mitRCN160510140837 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' - TeIn Type Test N 'TVD 12377 Tubing 0 0 0 0 PTD 2022230 yp i SPT Test psi 3094.25 1 IA o 0 0 0 j Interval OTHER P/F F V OA 0 1180 , 1080 - 1010 Notes: First attempt to pressure test OA on NS-22 surface casing repair.MIT-OA to 1000 psi as per Sundry 316-246. SCANNED SEP 2 7 2,016 Wednesday,May 11,2016 Page 1 of 1 • Aik MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �t 5Ic � DATE: 5/10/2016 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Repair Petroleum Inspector Northstar NS-22 Hilcorp Alaska LLC PTD 2022230; Sundry 316-246 5/6/2016: I traveled to Hilcorp Alaska's Northstar Island to witness a surface casing repair on NS-22. On arrival to Northstar I met with Hilcorp's Northstar supervisor Konrad Schruf. We discussed their procedure for the surface repair on NS-22. When I arrived at NS-22 they were in the process of removing a 3 foot section of the 20" conductor to inspect the leak in the surface casing. Once the conductor was removed they removed the cement from the 13 3/8" surface casing. Once the cement was removed from the casing and cleaned up and inspection was performed. No definite hole was found in the surface casing. The bottom of the top collar showed lot of corrosion and looked to be damp. Konrad feels that it's a thread leak on the bottom of the top collar. I told Konrad that they need to get with the AOGCC engineers on how to repair it. 5/7/2016: I received a phone call from Hilcorp Northstar representative Konrad Schruf telling me that they had put some nitrogen pressure on the outer annulus of NS-22 and found a leak. He said the leak is under the collar that supported their cellar floor. The collar was removed and the hole was found in the surface casing. He provided pictures at my request. 5/10/2016: I returned to Northstar Island today to inspect the surface casing repair on Northstar NS-22. A sleeve had been welded on the surface casing to isolate the leak — refer to the attached pictures. Summary: I performed 2 separate inspections of the surface casing repairs on Northstar NS-22. Additional photos were provided by Hilcorp showing the leak in the casing. 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P 631titik 4.,.I4 ,..4. 1 t' 17:1:40.,ill 41 tom,tk; # w --. r ')': 7i ' * I '4111I .. t i . y� �wl1 ., `' lMS — R ' itio f4 iiii 111ililliii"11111-"11 .. >a INN ... r1 . I" a. 2016-0510_S urfac e_c sg_Northstar_NS 22_bn.docx Page 8 of 8 tiOF 71, • • 1.)- ��y/��s� THE STATE Alaska Oil and Gas 0, tl, 0f Conservation Commission _. ALASI�:A .01'14 t �� 333 West Seventh Avenue 11 ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA 9 Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager ;,Hilcorp Alaska, CANNE 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,NS-22 Permit to Drill Number: 202-223 Sundry Number: 316-246 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6148 Cathy P. Foerster /--7 - Chair DATED this .-0-t4—day of April, 2016. RBDMS Lv APR 2 9 2016 RECEIVED • STATE OF ALASKA • APR 2 2' 2t016 • ALASKA OIL AND GAS CONSERVATION COMMISSION d 1 4'-\'"C( IL . APPLICATION FOR SUNDRY APPROVALS A.OGCG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Repair Surface Casing U - 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q 202-223 ' 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23128-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No ❑ NORTHSTAR UNIT NS-22 9.Property Designation(Lease Number): 10.Field/Pool(s): OCS Y-0181 - Northstar Field/Northstar Oil " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,886' ' 11,141' - 12,860' 11,121' 3,780 12,295' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2;13Cr80 12,303' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2"Bkr Lnr Top Pkr&7"x 5"Bkr ZXP Pkr 10,458MD/9,293TVD,12,257MD/10664TVD, 12,307MD/ 10,702TVD and 1,142MD/ and 3-1/2"TRM-4E SSSV 1,127TVD 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 5/2/2016 Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman ' '?I Email twellman(e hilcorp.com Printed Name Mike Dunn Title Operations Manager >/ Signature Phone 777-8382 Date 4;22/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 9i BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: y- tah.,,4 .t c c_waw. - its.zr c.4 t_ .7 .S c,&5, . r6 o [ ( W-c X .2-j•2 f i, r-,_--e-es . Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No El' Subsequent Form Required: J0 -- 410 1 RBDMS 0/ APP. 2 9 2016 a647,.. )ciLe.4„,(4,......._ TPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: q...,_ 1.4, —1 Submit Form and Form 10-403 R ed 11/2015 RrtvaJ1PIoAlsI/alId for 12 months from the date of approval. Attachments in Duplicate �//,,/ „,.5z i/.z z.•/c. • • Repair SC Leak Well: NS-22 PTD: 202-223 I-Iikorp Alaska.Lb API: 50-029-23128-00 Well Name: NS-22 API Number: 50-029-23128-00 Current Status: Online Rig: N/A Estimated Start Date: May 2, 2016 Estimated Duration: 14 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 202-223 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Maximum Expected BHP: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Max. Anticipated Surface Pressure: 3,780psi (During well SI on 06/13/15) Brief Well Summary: NS-22 is a naturally flowing production well. The well was SI from June 2010—March 2015 due to a leak in the surface casing. During diagnostics in June 2010, the leak was identified at 4' below the OA valve during an MIT- OA w/diesel. In March 2015 the tubing plug was pulled, the well passed an MIT-IA to 2500psi, additional instrumentation was installed and the well was returned to production under Sundry#315-088 for a surface casing leak and has special operating conditions. The well has remained online since this time and has shown no signs of worsening of the leak. An attempt to repair the SC leak by pumping WeIlLock into the surface casing . x,conductor annulus was unsuccessful on 04/14116. 06/06/10: NS reports leaking wellhead equipment below OA valve 06/07/10: MIT-OA Failed; diesel broach to surface confirming SC 06/11/10: Set PXN plug @ 12236' md, MIT-T Passed to 2500 psi, MIT-IA Passed to 2500 psi 06/26/10: Liquid leak rate pumping down OA—2.8 gpm @ 140 psi 06/27/10: SC leak found @ 4' 12/19/10: Operator reported 2-3 quarts of diesel leaked into the cellar 10/11/13:Tubing hanger void test Failed 10/15/13: Set two way check, tubing hanger void test Passed to 5000psi, change tree to dry hole tree, pull two way check. 03/12/15: MIT-IA Passed to 2500ps 03/13/15: Instrumentation installed, Sundry Approved and return well to production 02/01/16: To date the well has burped a total volume of 71.5gals, in large part due to high ambient temps in the summer months. 04/06/16: Place 2 stage treatment of WeIlLock into SCxConductor annulus. 04/14/16: MIT-OA Failed; diesel returns from tap conductor port OA Status: Closed shoe. During initial completion, the OA was down-squeezed with 33bbls of cement followed by 190bbls of water and diesel. The estimated TOC is at^'3482' and or—220' above the SC shoe. t wr, SC Leak Depth/Rate: Leak was determined to be 4' below the OA valve, or^'1.5' below the cellar floor. This was identified by fluid packing the OA then pumping N2 down the OA while taking fluid returns from the conductor. Once gas returns were observed,the OA pressure was bled down and a plumb bob was put through the OA casing valve until a • • Repair SC Leak Well: NS-22 • PTD: 202-223 Hilcorp Alaska,LL API: 50-029-23128-00 fluid level was found. A subsequent leak rate was observed at 2.8 gpm on 6/26/10 while pumping diesel down • the OA at 140 psi.Two weeks prior OA pressured to 1200 psi with pressure losses of only 90 psi/15 min. Objective: To expose and repair the hole in the 13-5/8" surface casing by welding an external patch around the leak site. • Timing: Proposed timing is to begin the 15t week of May 2016. The current time extension was approved to shut in the well after April 30, 2016. We would request to continue flowing the well through the 15t week of May. The justification for extending into the 1st week of May is based upon ensuing all materials on are location (Northstar island) prior to beginning the prep &excavation. Currently the patch materials are being rolled and machined and will be routed north as soon as they are completed. The final piece for justification is to align the work with our crews to minimize the number of shift changes during the repair. Procedure: Operations 1. Remove wellhouse and begin to thaw ground. 2. Erect scaffolding for access platform for slickline work. Slickline 3. RU SL unit. 4. Pressure test PCE to 300psi low/4000psi high. ' 5. RIH and set 3-1/2" PXN Plug at 12,295' md. 6. Bleed tubing to flowline pressure ("'750psi)to confirm set. a. If plug does not hold, set a 3-1/2" Evo-Trieve plug at 12,180' md. Bleed to header pressure to confirm set. b. Passing criteria: Opsi buildup for 30 min. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. 7. Close SSSV and bleed down to Opsi and monitor for signs of leakage. 8. RD SL unit. Operations 9. Complete an ACWR (Area Civil Work Request) which includes a locate for all utilities, thermosyphons and all underground infrastructure. 10. Bleed down T/I/O to Opsi. 11. Disconnect flowline and instrumentation. Tree&Wellhead 12. Verify tubing, IA and OA pressures have been bled to Opsi. 13. Close the master valve. 14. Remove SSV barrel. 15. Close the IA&OA casing valves and remove the risers. 16. Install tapped flange w/standard annulus jewelry. Pressure test flange to 2500psi. 17. Contingency — If upper tree is determined to be an obstacle/hindrance to work area or moving equipment in/out of repair area. a. Pressure test against the master valve to 300psi low and 4500psi high. b. Unbolt and remove the upper production tree. c. Install dry hole tree (master valve, swab valve &tree cap). Repair SC Leak • . Well: NS-22 PTD: 202-223 Hilcorp Alaska,Lb API: 50-029-23128-00 d. Pressure test the upper tree assembly to 4500psi. Operations 18. Excavate and install shoring to a depth of—10' below pad level and rade out the frpnt for secondary egress. lE l/ ,�: � 1_,.�s�p c Wry- C-t"�.w Er .`,rJJ a. Adjacent wells (NS-21 & NS-23) to be shut in once use of excavator begins until shoring box iscel< installed. b. Excavation to be monitored and inspected daily for continued use. 19. Install high volume water pumps into a low spot in the floor of the excavation. 20. Deconstruct and remove the existing well cellar. 21. Install secondary containment around lower edge of conductor. 22. Install clamp to secure landing ring of conductor to the wellhead. 23. Drill holes (cold cutting drill bit) in the conductor and remove cement as needed to expose clean casing for inspection. 24. Once a final depth is determined where uncorroded surface casing is found, drill additional holes (minimum of 3 @ 90deg, 180deg & 270deg) to confirm depth of competent cement and good surface casing is found. 25. Flush conductor with water from the upper inspection holes while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 26. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined on site prior to proceeding with accurate gas readings and fluid returns observed. b. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 27. Cut and remove additional conductor from this depth up. a. Prior to cutting conductor install continuous gas monitoring for LEL's from the conductor. b. Primary cutting option is to utilize a matebo saw with a cold cutting blade. c. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. 28. Chip away excess cement and WellLock from the surface casing. Buff and prepare surface casing for inspection and welding. a. Once final patch length is determined,cut patch to required length. 29. Inspection department to UT the exposed surface casing. a. Areas to weld bands to for external patch to be identified marked and inspected on a grid to ensure competency for welds. b. The tubing tally lists a 2.3' pup joint below the wellhead and the external patch will require bands to be welded above and below this connection so that the patch will be around the collar. c. If leak site can't be visually determined, use compressed air to pressure OA and spray bottles of soap to determine leak site is at the collar connection. 30. Install clamshell patch with bands pre-installed and weld circumferentially to the surface casing and vertically to the other patch half. a. Patch material: A572-13A Grade 50, ID=14-5/8", OD=15-1/8". b. Band material:A572 Grad50, thickness=5/8". 31. Inspect the welds to ensure competency. 32. Conduct an MIT-OA to 1000psi. 33. Weld external alignment band to the conductor. 34. Weld on new conductor extension. a. Old conductor to be used if able to be salvaged. • Repair SC Leak II Well: NS-22 PTD: 202-223 Mean)Alaska,LLQ API: 50-029-23128-00 i b. New conductor material: 20", 129.33#,X-56 35. Rebuild well cellar and backfill ground around conductor and cellar. a. Deconstructed cellar to be used if able to be salvaged. Tree &Wellhead 36. Verify tubing, IA and OA pressures are still Opsi. 37. Install SSV barrel. 38. Close the IA&OA casing valves and install the gauge risers. 39. Contingency—If a dry hole tree was installed. a. Close the master valve. b. Pressure test against the master valve to 300psi low and 4500psi high. c. Unbolt and remove the dry hole tree. d. Install upper production tree. e. Pressure test the upper tree assembly to 4500psi. Operations 40. Re-install flowline, instrumentation, and wellhouse. 41. Equalize pressure above SSSV and open SSSV. 42. Use jumper to increase tubing pressure to^'3800psi. Slickline 43. RU SL unit. 44. Pressure test PCE to 300psi low/4000psi high. 45. RIH and pull 3-1/2" PXN Plug at 12,295' md.• a. If a 3-1/2" Evo-Trieve plug was set, pull from 12,180' md. 46. RD SL unit. STATE OF ALASKA • ALL OIL AND GAS CONSERVATION COASION APR 2 2 2016 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Return to Production ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Install WellLock 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 202-223 3.Address: Stratigraphic 11] Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23128-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: OCS Y-0181 NORTHSTAR UNIT NS-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Northstar Field/Northstar Oil 11.Present Well Condition Summary: Total Depth measured 12,887 feet Plugs measured N/A feet true vertical 11,141 feet Junk measured N/A feet 10,458, 12,257& Effective Depth measured 12,860 feet Packer measured 12,307 feet 9,293, 10,664& true vertical 11,121 feet true vertical 10,702 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED APR 2 9 2010 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13Cr80/Vam-Ace 12,303' 10,699' 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2" 10,458MD/9,293TVD, Bkr Lnr Top Pkr&7" 12,257MD/10,664TVD, Packers and SSSV(type,measured and true vertical depth) x 5"Bkr ZXP Pk 3-1/2"TRM-4E SSSV 12,307MD/10,702TVD 1,142MD/1,127TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 969 46,588 68 1,028 796 Subsequent to operation: 948 43,173 197 23 797 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-154 Contact Taylor Wellman Email twellmanAhilcorp.com Printed Name ike Dun,- Title Operations Manager Signature 7z4VG Phone 777-8382 Date 4/21/2016 Form 10-404 Revised 5/2015 Submit Original Only 1-, -.41,14 RBDMS Lv APR 2 2 2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-22 N/A 50-029-23128-00-00 202-223 3/7/16 4/15/16 Daily Operations: 3/2/2015 -Wednesday No activity to report. 3/3/2015 -Thursday No activity to report. 3/4/2015 - Friday No activity to report. 3/5/2015 -Saturday No activity to report. 3/6/2015 -Sunday No activity to report. 3/7/2015- Monday Hold ATP meeting, obtain permits, and check cellar atmosphere for entry. Clean &vac out well cellar. Mark holes to be drilled —4" down from top of conductor& 6" (center to center)as measured from cement return port. Use mag drill to drill 2" holes (9 in total) around the conductor. 3/8/2015-Tuesday Re-issue permits and check cellar atmosphere for entry. Begin cleaning operations of 13-5/8"surface casing x 20" conductor annulus. Flush water through each inspection hole while vac'ing returns from cement return port. Apply heater to cellar to dry out& inspect w/ boroscope. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-22 N/A 50-029-23128-00-00 202-223 3/7/16 4/15/16 Daily Operations: 3/30/2015 Wednesday No activity to report. 3/31/2015 -Thursday No activity to report. 4/1/2015 - Friday No activity to report. 4/2/2015 -Saturday No activity to report. 4/3/2015-Sunday No activity to report. 4/4/2015- Monday Hold PJSM and stage chemicals/mixing equipment outside of well house.Take temperatures of surface casing, conductor and conductor fill.;Begin Mixing. Measure R1.Add R2.Add H1. Add A2. Start Pouring. Finished Pouring. QC Sample. Pressured up to 10 psi with 30°F air. Held pressure at 10 psi. Check Fluid Levels. Re-pressure up for 30 minutes.;Begin monitoring temperatures at half hour intervals. Noticed WeIlLock level dropped. Surface sample viscous but pourable. Continue to monitor temps throughout the night. Surface sample completely set up but still tacky to the touch. Annuls sample not quite set up. 4/5/2015-Tuesday Inner portion of WellLock setting up but still tacky. Outside still soft;lnner portion of WellLock set up;Outer WellLock setting up but still tacky. Stopped monitoring due to heat generation over. Waited for product to cure for before second batch. Closed in the well to bring up temperature and OA pressure. Once OA bled, opened the well to lower SC temp to put the OA on a vacuum and contract SC. Started Mixing WeIlLock w/LockCem mixture, Product at 60 degrees. Poured WeIlLock/LockCem. Waited on WeIlLock/LockCem to set up. Started monitoring temps. No changes in temp. Break for Dinner. HES RDMO. Operations monitoring temps overnight. WeIlLock/LockCem surface sample set up but tacky. Will wait one week then MIT-OA. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-22 N/A 50-029-23128-00-00 202-223 3/7/16 4/15/16 Daily Operations: "fly 4/13/2016-Wednesday No activity to report. 4/14/2016-Thursday No activity to report. 4/15/2016- Friday Initial T/I/0=1000/24/1.3psi. Well online &flowing. Conduct MIT-OA w/diesel- Failed.While pressuring up on OA, diesel returns observed coming from West tapped conductor hole. Stop pumping and OA pressure bled down quickly. Bleed down OA and RD equipment. 4/16/2016 -Saturday No activity to report. 4/17/2016-Sunday No activity to report. 4/18/2016- Monday No activity to report. 4/19/2016-Tuesday No activity to report. + � � Northstar Unit Well: NS-22 SCHEMATIC Last Completed: 1/27/2003 Hilcorp Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(CB 15.9) ii,i, Size Type Wt/Grade/Conn ID Top Btm Fi20" Conductor 169/X-56/N/A N/A Surface 201' , __ 1 20 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' 9 5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 13-3/8"4 TUBING DETAIL Wel ILock 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' JEWELRY DETAIL opt ? No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" .`, 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL • Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open I �I 4 WELL INCLINATION DETAIL ore. KOP @ 321' Max Hole Angle=43 deg.@ 11,377' 9-5/8" • OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 7" 360 sx Class"G"in 8-1/2"Hole 1 I 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole ►r+[ 7 TREE&WELLHEAD 1 Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 1 GENERAL WELL INFO API:50-029-23128-00-00 111 .1 11 Drilled&Completed by Nabors 33E-2/2/2003 I "1 12 PerfAdd-7/9/2007 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7" r INshak Sands 4-1/2" J TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Revised By:TDF 4/21/2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,April 20,2016 P.I.Supervisor `�� 4 Z6(t SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC NS-22 FROM: Bob Noble NORTHSTAR UNIT NS-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-22 API Well Number 50-029-23128-00-00 Inspector Name: Bob Noble Permit Number: 202-223-0 Inspection Date: 4/14/2016 Insp Num: mitRCNl60414171152 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-22 , Type Inj N-TVD 3926 Tubing woo woo - PTD 2022230 Type Test SPT Test si! 98L5 IA 24.2 - 25.6 . YP P , Interval OTHER P/F I F OA 1.3 . 360. — — ------------_-- - ------------- ------ Notes: Diagnostic MIT-OA following Wellock repair of surface casing.A MIT-OA was going to be performed to 375 psi on the OA.OA was pumped up to 360 psi and fluid was coming out of the conductor. Lyn( 5 Oil Ccs "21''. SCANNED SEP 2 7 2016 Wednesday,April 20,2016 Page 1 of 1 • h-o , ,k)s -z z Zi%zzz.3 Regg, James B (DOA) From: Noble, Robert C (DOA) /� (7(1 C0 Sent: Friday,April 15, 2016 8:40 AM 11 ` To: Regg, James B (DOA) 1 Subject: Northstar Attachments: NS-meter-prove-pdf Jim I have a couple things I need to talk to you about Northstar yesterday. I went out for a MIT-OA on NS-22.The weather was double bad and it took me an hour to the tent to ride out in their van.They were going to have a return trip in an hour and I thought I wanted to catch that trip before I had to spend the hitch on Northstar due to weather. I wanted to catch the meter while I was there too. So when I got on the island I told them to start warming the meter up and start to prove. My plan was to go out to the MIT and get it pumped up and on the first 15 min I was going to go inspect the meter. Well we were pressuring up the OA to 375 psi.They would getclose to pressure and stop pumping y(and the pressure would slowly bleed down.They were saying it was because they were pumping through 1/2" needle valves and they were also filling the well up. Being a pump guy for 30 years it sure looked like they had a leak down hole to me. So I moved out of the wellhouse. I have taken a diesel shower before and don't really want another one. Long story short diesel finely started coming out of the cement line on the conductor, which means their patch job failed. So because of the MIT issues I missed the meter prove and was un-able to inspect the prover while proving. I did get the paperwork for the prove. And to boot all it went phase two on the beach and I was there for hours before they could figure out a way to convoy me back to camp. Bob Noble AOGCC 333 W. 7th Ave. Ste. 100 Anch AK. 99501 SCANNED KAY 1 201.7. Cell 907-299-1362 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Bob Noble at 907-299-1362 or bob.noble@alaska.gov 0=7.3* �,gNT OF T • • co, - .y United States Department of the Interior BUREAU OF SAFETY AND ENVIRONMENTAL ENFORCEMENT • �T� ,ygRcH��$,� Alaska OCS Region 3801 Centerpoint Drive,Suite 500 RECEIVED Anchorage,Alaska 99503-5823 MAR 032016 FEB 2 9 2016 AOGCC Mike Dunn, Operations Manager,North Slope Hilcorp Alaska, LLC 3800 Centerpoint Dr., Suite 1400 P z— 2-Z Anchorage,AK 99503 7°T1) Dear Mr. Dunn: Enclosed is the approved Application for Permit to Modify for the Northstar NS-22 well. BSEE includes the following conditions with our approval. • Notify this office a minimum of 3 business days prior to commencing the approved operations, in order to enable BSEE inspection of the operations. • Follow the incident reporting requirements of 30 CFR 250.187-190. Use the BSEE Alaska Region Drilling Alert Line (1-855-277-2733)to report incidents requiring immediate notification. • A copy of this permit(including all attachments) must be kept on location and made available to inspectors upon request during the permitted operation. • Conduct pressure testing of the repaired casing and provide the results of all testing conducted to confirm the repair. • Pressure test the well two additional times within the following year to ensure that the repair is holding and provide results to BSEE. RT: Nb-r-- d2o�: ¢.'✓ In the event the proposed repair option does not correct the casing leak, Hilcorp will be require ' to provide to this office a plan and schedule for additional repair activities regarding sealing the existing casing leak. Y(c If you have any questions about this approval, please contact Kyle Monkelien at(907) 334-5307 or via e-mail at kyle.monkelien@bsee.gov. Sincerely, s'C. ► HEQ MAR 9 9 2016 7400°9 Kevin J. Pendergast, PE C' Regional Supervisor, Field Operations Enclosure: APM NS-22 cc: State of Alaska, AOGCC s • • U.S.Department of the Interior Submit original plus THREE copies,with ONE copy OMB Control No.1014-0026 Bureau of Safety and Environmental marked"Public Information." OMB Approval Expires 05/31/2017 Enforcement(BSEE) Application for Permit to Modify (APM) 1.WELL NAME(CURRENT) 2. SIDETRACK NO. 3. BYPASS NO.(CURRENT) 4. OPERATOR NAME and ADDRESS NORTHSTAR UNIT NS-22 (CURRENT) N/A (Submitting office) Hilcorp Alaska LLC 5. API WELL NO.(12 digits) 6. START DATE(Proposed)7.ESTIMATED DURATION(DAYS) 3800 Centerpoint Dr 50-029-23128-00 2/19/2016 3 Suite 1400 Anchorage Alaska 99524 8. 9. If revision, list changes: 0 Revision R E9 E I sE D WELL AT TOTAL DEPTH WELL AT SURFACE image,A ake 10.LEASE NO. 13.LEASE NO. 2 d o� U L 9016 OCS Y-0181 ADL312799 FEBf CD 11.AREA NAME 14.AREA NAME REGIOffit SUPERVISOR Beechy Point Beechy Point FIELD OPERATIONS 12.BLOCK NO. 15.BLOCK NO. r mumiuriranwroferen 516 515 PROPOSED OR COMPLETED WORK 16. PROPOSED OR COMPLETED WORK(Describe in Section 17) PLEASE SELECT ONLY ONE PRIMARY TYPE IN BOLD AND AS MANY SECONDARY TYPES AS NECESSARY. Completion Workover: Enhance Production ❑ Initial Completion 0 Change Tubing 0 Acidize ❑ Reperforation 0 Casing Pressure Repair 0 Artificial Lift ❑ Change Zone 0 Wash/Desand Well O Modify Perforations 0 Abandonment of Well Bore: 0 Jet Well 0 Utility 0 Permanent Abandonment 0 Hydraulic Fracturing O Initial Injection Well 0 Temporary Abandonment 0 Information: ❑ Additional Fluids for Injection ❑ Plugback to Sidetrack/Bypass 0 Surface Location Plat El Other Operations 0 Site Clearance 0 Change Well Name El Describe Operation(s) 17. BRIEFLY DESCRIBE PROPOSED OPERATIONS(Attach prognosis): See attached prognosis 16. LIST ALL ATTACHMENTS(Attach complete well prognosis and attachments required by 30 CFR 250.465;250.513(a)through(d);250.514(d); 250.516(a);250.517(d)(8);250.517(d)(9)(I); 250.613(a)through(d);250.614(d);250.616(a);250.616(0(4);250.617(d);250.617(h)(1);250.617(h)(2)((1; 250.1706(a);250.1706(0(4);250.1707(d);250.1709;250.1712(a)through(g);250.1721(a);250.1722(a);or 250.1743(a). Prognosis,Schematic,current wellhead schematic&proposed wellhead schematic 19. Rig Name or Primary Unit(e.g.,Wireline Unit,Coil Tubing,Snubbing Unit,etc.) 20.The greater of SITP or MASP(psi):3900 21. Type of Safety Valve(SV):ESCSSV❑sscsv❑N/A 22. SV Depth BML(ft): '1142 23. Rig BOP(Rams) 24. Rig BOP(Annular) Size: Working Pressure Test Pressure Working Pressure Test Pressure (inches) (psi) (psi) (psi) (psi) Low/High: !__ Low/High: _ /__ 25. Coiled Tubing BOP: 26. Snubbing Unit BOP: 27. Wireline Lubricator: Working Pressure BOP Test Pressure Working Pressure Test Pressure Working Pressure Test Pressure (psi) (psi) (psi) (psi) (psi) (psi) Low/High: f____ _ Low/High: I Low/High:300 / 4200 28. CONTACT NAME: 29. CONTACT TELEPHONE NO.: 30. CONTACT E-MAIL ADDRESS: TAYLOR WELLMAN 907-777-8449 twellman@hilcorp.com 31. AUTHORIZING OFFICIAL(Type or print name) 32. TITLE Taylor Wellman Operations Engineer 33. AUTHO UR 34. DATE 2/19/2015 L_.. . 6,,, .p a„t_cI.,c 6 r t THIS SPACE FOR BSEE USE ONLY AP 6VED B TITLE DATE _ j� /j, BSEE Form BSEE-01 4(May 2014- Supersedes all previous versions of this form which may not be used.) Page 1 of 2 • Application for Permit to Modify(APM) Information Sheet 35) Question Information Questions Response Remarks A) Is H2S present in the well? If yes, ❑ YES then comment on the inclusion of a CD NO Contingency Plan for this operation. ❑ N/A B) Is this proposed operation the only El YES lease holding activity for the subject El NO lease? If yes, then comment. ❑ N/A C)Will all wells in the well bay and ❑ YES related production equipment be shut-in ❑ NO when moving on to or off of an offshore platform, or from well to well on the N/A platform? If not, please explain. D) If sands are to be commingled for this ❑ YES completion, has approval been ❑ NO obtained? 0 N/A E) Will the completed interval be within ❑ YES 500 feet of a block line? If yes, then ❑ NO comment. ❑ N/A F) For permanent abandonment, will ❑ YES casings be cut 15 feet below the ❑ NO mudline? If no, then comment. ❑ N/A CERTIFICATION: I certify that the information submitted is complete and accurate to the best of my knowledge. I understand that making a false statement may subject me to criminal penalties under 18 U.S.C. 1001. Name and Title: Torn Fouts Senior Ops/ Reg Tech Date: 2/1 9/2016 PAPERWORK REDUCTION ACT OF 1995(PRA)STATEMENT: The PRA(44 U.S.C.3501 et seq.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. BSEE uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory(43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.197. An agency may not conduct or sponsor,and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for reviewing the instructions,completing and filling out this form only is estimated to average 1 hour per response.The burden for the attachments required in the form range from 10 minutes to 1.5 hours depending on the requirement. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Safety and Environmental Enforcement,381 Elden Street, Herndon,VA 20170. BSEE Form BSEE-0124 (May 2014-Supersedes all previous versions of this form which may not be used.) Page 2 of 2 • • Repair SC Leak • Well: NS-22 PTD: 202-223 Ililcorp Alaeka,LL API: 50-029-23128-00 Well Name: NS-22 API Number: 50-029-23128-00 Current Status: Online Rig: N/A Estimated Start Date: March 1, 2015 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 202-223 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Maximum Expected BHP: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Max.Anticipated Surface Pressure: 3,780psi (During well SI on 06/13/15) Brief Well Summary: NS-22 is a naturally flowing production well. The well was SI from June 2010—March 2015 due to a leak in the surface casing. During diagnostics in June 2010,the leak was identified at 4' below the OA valve during an MIT- OA w/diesel. In March 2015 the tubing plug was pulled,the well passed an MIT-IA to 2500psi, additional instrumentation was installed and the well was returned to production under Sundry#315-088 for a surface casing leak and has special operating conditions. The well has remained online since this time and has shown no signs of worsening of the leak. 06/06/10: NS reports leaking wellhead equipment below OA valve 06/07/10: MIT-OA Failed; diesel broach to surface confirming SC 06/11/10: Set PXN plug @ 12236' md, MIT-T Passed to 2500 psi, MIT-IA Passed to 2500 psi 06/26/10: Liquid leak rate pumping down OA^'2.8 gpm @ 140 psi 06/27/10: SC leak found @ 4' 12/19/10: Operator reported 2-3 quarts of diesel leaked into the cellar 10/11/13:Tubing hanger void test Failed 10/15/13: Set two way check, tubing hanger void test Passed to 5000psi, change tree to dry hole tree, pull two way check. 03/12/15: MIT-IA Passed to 2500ps 03/13/15: Instrumentation installed,Sundry Approved and return well to production 02/01/16:To date the well has burped a total volume of 71.5gals, in large part due to high ambient temps in the summer months. OA Status: Closed shoe. During initial completion,the OA was down-squeezed with 33bbls of cement followed by 190bbIs of water and diesel. The estimated TOC is at 3482' and or^'220' above the SC shoe. SC Leak Depth/Rate: Leak was determined to be 4' below the OA valve,or^'1.5' below the cellar floor.This was identified by fluid packing the OA then pumping N2 down the OA while taking fluid returns from the conductor. Once gas returns were observed,the OA pressure was bled down and a plumb bob was put through the OA casing valve until a fluid level was found. A subsequent leak rate was observed at 2.8 gpm on 6/26/10 while pumping diesel down the OA at 140 psi.Two weeks prior OA pressured to 1200 psi with pressure losses of only 90 psi/15 min. . • Repair SC Leak • II Well: NS-22 PTD: 202-223 Hilcorp Alaska,LLQ API: 50-029-23128-00 Objective: To mitigate flow of hydrocarbons to surface through the SCxConductor annulus. Timing: Scheduled for late February 2016. The current timing for repair under Sundry#315-088 is for the well to be repaired or shut in on February 26, 2016.The proposed procedure would allow the well to remain online until the scheduled repair can be conducted or an alternative repair option (excavation &external patch) can be completed in late ice road season (approx.April 1, 2016). The timing is based on the following reasoning for the excavation repair: 1. Minimal amount of water influxing into the excavation. The frozen sea should provide the minimal amount of water to be handled while the excavation is in place based on best practices shared from other operators. 2. Extreme temperatures. The repair time in late ice road season vs. early ice road season will allow for avoiding the worst months in terms of extreme cold for exposure to personnel. Procedure: 1. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. 10 gal of RG-2014 has been pumped into the conductor via the cementing port on 05/02/09. Use of a citrus based hand cleaner is the recommended solvent for final cleaning of the RG- 2401 from the SC&conductor walls. 2. Bleed OA pressures to 0 psi. 3. Drill holes in the upper section of the 20" surface casing w/non-sparking bit and mag drill. a. Holes will be—2" diameter, circumferential and evenly spaced around the conductor. b. The conductor is 20", 169#,X-56, ID=18.376", Burst=3910psi, Collapse=2500psi. 4. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. Use of a steam wand washing the annulus with water and solvent will be conducted. 5. Place heater in wellhouse circulating air through the conductor to dry it out of any fluids. 6. Use a boroscope down the conductor to inspect 13-3/8" surface casing for corrosion and leak site. 7. Have UT thickness testing conducted around the upper exposed portion of the 13-3/8" SC to check for possible drilling damage. 8. Contingency: If additional room for UT inspection to be completed is needed, use saw to cut between drilled holes to widen inspection windows. Possible use of nitrogen purge into the OA w/ N2 bottles. This will be determined by how well the conductor can be cleaned and remain free of any possible flammable materials. 9. Contingency: If there is not a hard bottom in the conductor add in steps for a top job to be pumped. 10. Fill the well cellar with water up to a level just below the cement return port. This will act as an additional temperature sink to absorb heat while the treatment is curing. 11. Mix WeIlLock as per recommended volumes, concentration, and pumping procedure to place a volume (minimum of 6.5gal or 1') into the lower portion of the conductor. a. The SCxConductor volume=0.155bpf or 6.5gpf b. Treatment volume will be approx. 11 gal &will come up to just below the cementing port. 12. Allow WeIlLock to cure for 2-3 days. a. Monitor temperature during curing phase. (13. Conduct an MIT-OA to 375psi w/diesel. a. Pressure Testing Justification: Leak rate observed is ^2.8gpm at 140psi and has demonstrated leaking diesel into the cellar at 5-10psi on the OA. OA pressures prior to SC leak development fluctuated between 0-300 psi during �v'v'y rations. • Northstar Unit 11 • • Well: NS-22 SCHEMATIC Last Completed: 1/27/2003 Mean)Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20'I 1 20" Conductor 169/X-56/N/A N/A Surface 201' 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 I• --,i 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' i` ' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 13-3/8" irl TUBING DETAIL 3-1/2" I Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' Leak @ Approx.4• JEWELRY DETAIL ,41.; 2 No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch at 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open 4 WELL INCLINATION DETAIL KOP @ 321' Max Hole Angle=43 deg.@ 11,377' 9- 5/8' OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8-1/2"Hole 1 . 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole ''''''44 ►:. 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 1 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 L ... J 11 Drilled&Completed by Nabors 33E-2/2/2003 r12 Perf Add-7/9/2007 im13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"a 6 1 Ivishak Sands 4-1/2" T®=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 2/19/2016 14 • • Northstar Unit Well: NS-22 PROPOSED Last Completed: 1/27/2003 Ililcorp Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(C615.9) Size Type Wt/Grade/Conn ID Top Btm Li 20" Conductor 169/X-56/N/A N/A Surface 201' 20" tI i = . 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 1 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' x TUBING DETAIL 13-3/8"4 r WellLock 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' € JEWELRY DETAIL 'a 2 No Depth Item i 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" a 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) t 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open I` ' 4 iWELL INCLINATION DETAIL I; KOP @ 321' Max Hole Angle=43 deg.@ 11,377' 9-5/8" OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 6 7" 360 sx Class"G"in 8-1/2"Hole i 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole yili ►i 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI I Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 Illi _' J 11 Drilled&Completed by Nabors 33E-2/2/2003 • ■ 12 Perf Add-7/9/2007 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7" =--- --. ..-:Ivishak Sands 4-1/2"11 I► TD=12,887'(MD)/TD=11,142(1VD) PBTD=12,860'ELM(MD)/PBTD=11,121'(1VD) Reviseded By:TDF 2/17/2016 • • e ` : Public Information AnchoeiV U.S.Department of the Interior Submit original plus THREE copies,with ONE copy OMB Control N 1 -0026 'A/$skF® p�14 Bureau of Safety and Environmental marked"Public Information." OMB Approval Expires:O 1/ 17) Enforcement(BSEE) pfie2016 Application for Permit to Modify (APM) Kik' suaFis 1.WELL NAME(CURRENT) 2. SIDETRACK NO. 3. BYPASS NO.(CURRENT) 4. OPERATOR NAME and R41/ S� ) ONE/4,00080r NORTHSTAR UNIT NS-22 (CURRENT) N/A (Submltting Alask LLC N/A Hilcorp Alaska LLC 5. API WELL NO.(12 digits) 6. START DATE(Proposed)7.ESTIMATED DURATION(DAYS) 3800 Centerpoint Dr 50-029-23128-00 2/19/2016 3 Suite 1400 Anchorage Alaska 99524 g. 9. If revision, list changes: 0 Revision WELL AT TOTAL DEPTH WELL AT SURFACE 10.LEASE NO. 13.LEASE NO. OCS Y-0181 ADL312799 11.AREA NAME 14.AREA NAME Beechy Point Beechy Point 12.BLOCK NO. 15.BLOCK NO. 516 515 PROPOSED OR COMPLETED WORK - 16. PROPOSED OR COMPLETED WORK(Describe in Section 17) PLEASE SELECT ONLY ONE PRIMARY TYPE IN BOLD AND AS MANY SECONDARY TYPES AS NECESSARY. Completion Workover: Enhance Production ❑ Initial Completion 0 Chango Tubing 0 Acidize ❑ Reperforation 0 Casing Pressure Repair 0 Artificial Lift ❑ Change Zone 0 Wash/Desand Well ❑ Modify Perforations 0 Abandonment of Well Bore: 0 Jet Well 0 utility 0 Permanent Abandonment 0 Hydraulic Fracturing O Initial Injection Well 0 Temporary Abandonment 0 Information: O Additional Fluids for Injection 0 Plugback to Sidetrack/Bypass 0 Surface Location Plat El Other Operations 0 Site Clearance 0 Chainge Well Name El Describe Operation(s) 17. BRIEFLY DESCRIBE PROPOSED OPERATIONS(Attach prognosis): See attached prognosis 16. LIST ALL ATTACHMENTS(Attach complete well prognosis and attachments required by 30 CFR 250.465;250.513(a)through(d);250.514(d); 250.516(a);250.517(d)(8);250.517(d)(9)(i);250.613(a)through(d);250.614(d);250.616(a);250.616(f)(4);250.617(d);250.617(h)(1);250.617(h)(2)O; 250.1706(a);250.1706(0(4);250.1707(d);250.1709;250.1712(5)through(g);250.1721(8);250.1722(a);or 250.1743(a). Prognosis,Schematic,current wellhead schematic&proposed welthead schematic 19. Rig Name or Primary Unit(e.g.,Wireline Unit,Coil Tubing,Snubbing Unit,etc.) 20.Tho greater of SITP or MASP(psi):3900 21. Type of Safety Valve(SV):EI SCSSV DSSCSVE N/A 22. SV Depth BML(ft): 1142 23. Rig BOP(Rams) 24. Rig BOP(Annular) Size: Working Pressure Test Pressure Working Pressure Test Pressure (inches) (psi) (psi) (psi) (psi) Low/High: / -_. - Low/High: __.__I___ 25. Coiled Tubing BOP: 26. Snubbing Unit BOP: 27. Wireline Lubricator: Working Pressure BOP Test Pressure Working Pressure Test Pressure Working Pressure Test Pressure (Psi) (psi) (Psi) (Psi) (Psi) (Psi) Low/High: __i_ _ ___ Low/High:_/ Low/High 300 i 4200 28. CONTACT NAME: 29. CONTACT TELEPHONE NO.: 30. CONTACT E-MAIL ADDRESS: TAYLOR WELLMAN 907-777-8449 tweilman@hilcorp.com 31. AUTHORIZING OFFICIAL(Type or print name) 32, TITLE Taylor WellmanOperations Engineer 33. AUTHOBIZI 31G�I uR 34. DATE 015 f, -5�� r - {{22 4 ,/ O,y o,-�Je..( a d j THIS SPACE FOR BSEE USE ONLY APR/A.6 BY: c !TITLE {., fo DATE / BSEE Form BSEE-0124(May 2014- Supersedes all previous versions of this form which may not be used.) Page 1 of 2 . • • Public Information Application for Permit to Modify(APM) Information Sheet 35) Question Information Questions Response Remarks A) Is H2S present in the well? If yes, ❑ YES then comment on the inclusion of a 0 NO Contingency Plan for this operation. ❑ N/A B) Is this proposed operation the only ❑ YES lease holding activity for the subject ID NO lease? If yes, then comment. ❑ N/A C)Will all wells in the well bay and ❑ YES related production equipment be shut-in ❑ when moving on to or off of an offshore NO platform, or from well to well on the E1 N/A platform? If not, please explain. D) If sands are to be commingled for this El YES completion, has approval been ❑ NO obtained? [l N/A E)Will the completed interval be within ❑ YES 500 feet of a block line? If yes,then ❑ NO comment. EJ N/A F) For permanent abandonment, will ❑ YES casings be cut 15 feet below the ❑ NO mudline? If no, then comment. E N/A CERTIFICATION: I certify that the information submitted is complete and accurate to the best of my knowledge. I understand that making a false statement may subject me to criminal penalties under 18 U.S.C. 1001. Name and Title: Tom Fouts Senior Ops/ Reg Tech Date: 2/19/2016 PAPERWORK REDUCTION ACT OF 1995(PRA)STATEMENT: The PRA(44 U.S.C.3501 et seq.)requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. BSEE uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory(43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.197. An agency may not conduct or sponsor,and a person is not required to respond to,a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for reviewing the instructions,completing and filling out this form only is estimated to average 1 hour per response.The burden for the attachments required in the form range from 10 minutes to 1.5 hours depending on the requirement. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer,Bureau of Safety and Environmental Enforcement,381 Elden Street,Herndon,VA 20170. BSEE Form BSEE-0124 (May 2014-Supersedes all previous versions of this form which may not be used.) Page 2 of 2 • • Public Information • Repair SC LeakWell: NS-22 PTD:202-223 Ililatrp Alaska,LI) API:50-029-23128-00 Well Name: NS-22 API Number: 50-029-23128-00 Current Status: Online Rig: N/A Estimated Start Date: March 1, 2015 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Torn Fouts 777-8398 Permit to Drill Number: 202-223 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Maximum Expected BHP: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Max. Anticipated Surface Pressure: 3,780psi (During well SI on 06/13/15) Brief Well Summary: NS-22 is a naturally flowing production well. The well was SI from June 2010-March 2015 due to a leak in the surface casing. During diagnostics in June 2010,the leak was identified at 4' below the OA valve during an MIT- OA w/diesel. In March 2015 the tubing plug was pulled,the well passed an MIT-IA to 2500psi, additional instrumentation was installed and the well was returned to production under Sundry#315-088 for a surface casing leak and has special operating conditions. The well has remained online since this time and has shown no signs of worsening of the leak. 06/06/10: NS reports leaking wellhead equipment below OA valve 06/07/10: MIT-OA Failed;diesel broach to surface confirming SC 06/11/10:Set PXN plug @ 12236' md, MIT-T Passed to 2500 psi, MIT-IA Passed to 2500 psi 06/26/10: Liquid leak rate pumping down OA"'2.8 gpm @ 140 psi 06/27/10:SC leak found @ 4' 12/19/10: Operator reported 2-3 quarts of diesel leaked into the cellar 10/11/13:Tubing hanger void test Failed 10/15/13:Set two way check,tubing hanger void test Passed to 5000psi,change tree to dry hole tree, pull two way check. 03/12/15: MIT-IA Passed to 2500ps 03/13/15: Instrumentation installed,Sundry Approved and return well to production 02/01/16:To date the well has burped a total volume of 71.Sgals, in large part due to high ambient temps in the summer months. OA Status: Closed shoe. During initial completion,the OA was down-squeezed with 33bbls of cement followed by 190bbIs of water and diesel. The estimated TOC is at -3482' and or -220' above the SC shoe. SC Leak Depth/Rate: Leak was determined to be 4'below the OA valve,or-1.5' below the cellar floor.This was identified by fluid packing the OA then pumping N2 down the OA while taking fluid returns from the conductor. Once gas returns were observed,the OA pressure was bled down and a plumb bob was put through the OA casing valve until a fluid level was found. A subsequent leak rate was observed at 2.8 gpm on 6/26/10 while pumping diesel down the OA at 140 psi.Two weeks prior OA pressured to 1200 psi with pressure losses of only 90 psi/15 min. � s Repair SC Leak Public Information Well: NS-22 PTD:202-223 flacon,AIn,kn,i.I. API:50-029-23128-00 Objective: To mitigate flow of hydrocarbons to surface through the SCxConductor annulus. Timing: Scheduled for late February 2016. The current timing for repair under Sundry#315-088 is for the well to be repaired or shut in on February 26, 2016.The proposed procedure would allow the well to remain online until the scheduled repair can be conducted or an alternative repair option(excavation &external patch) can be completed in late ice road season (approx.April 1, 2016). The timing is based on the following reasoning for the excavation repair: 1. Minimal amount of water influxing into the excavation. The frozen sea should provide the minimal amount of water to be handled while the excavation is in place based on best practices shared from other operators. 2. Extreme temperatures. The repair time in late ice road season vs. early ice road season will allow for avoiding the worst months in terms of extreme cold for exposure to personnel. Procedure: 1. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. 10 gal of RG-2014 has been pumped into the conductor via the cementing port on 05/02/09. Use of a citrus based hand cleaner is the recommended solvent for final cleaning of the RG- 2401 from the SC&conductor walls. 2. Bleed OA pressures to 0 psi. 3. Drill holes in the upper section of the 20"surface casing w/non-sparking bit and mag drill. a. Holes will be—2"diameter,circumferential and evenly spaced around the conductor. b. The conductor is 20", 169#,X-56, ID=18.376", Burst=3910psi,Collapse=2500psi. 4. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. Use of a steam wand washing the annulus with water and solvent will be conducted. 5. Place heater in wellhouse circulating air through the conductor to dry it out of any fluids. 6. Use a boroscope down the conductor to inspect 13-3/8"surface casing for corrosion and leak site. 7. Have UT thickness testing conducted around the upper exposed portion of the 13-3/8" SC to check for possible drilling damage. 8. Contingency: If additional room for UT inspection to be completed is needed, use saw to cut between drilled holes to widen inspection windows. Possible use of nitrogen purge into the OA w/ N2 bottles. This will be determined by how well the conductor can be cleaned and remain free of any possible flammable materials. 9. Contingency: If there is not a hard bottom in the conductor add in steps for a top job to be pumped. 10. Fill the well cellar with water up to a level just below the cement return port. This will act as an additional temperature sink to absorb heat while the treatment is curing. 11. Mix WeIlLock as per recommended volumes, concentration,and pumping procedure to place a volume (minimum of 6.5gal or 1') into the lower portion of the conductor. a. The SCxConductor volume =0.155bpf or 6.5gpf b. Treatment volume will be approx. 11 gal &will come up to just below the cementing port. 12. Allow WeIlLock to cure for 2-3 days. a. Monitor temperature during curing phase. 13. Conduct an MIT-OA to 375psi w/diesel. a. Pressure Testing Justification: Leak rate observed is ^'2.8gpm at 140psi and has demonstrated leaking diesel into the cellar at 5-10psi on the OA. OA pressures prior to SC leak development fluctuated between 0-300 psi during normal operations. ` . Public Information • Northstar Unit Well: NS-22 SCHEMATIC Last Completed: 1/27/2003 uncoil,Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2 (CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 16689/LX-8-506//N/A N/A Surface 201' 20" 13-3/8" Surface Btrc. 12.415 Surface 3,707' 7 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 I 1 i 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' " 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 133/8' TUBING DETAIL 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' Leak @ Ppprox4' JEWELRY DETAIL `' 2 No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,10=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open IL 4 WELL INCLINATION DETAIL KOP @ 321' Max Hole Angle=43 deg.@ 11,377' 95/8 OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8 1/2"Hole 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole Z� 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 IL VIE J', 11 Drilled&Completed by Nabors 33E-2/2/2003 '�iI� 12 Perf Add-7/9/2007 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"• 1 }Ivishak$axis 4-1/2" - ID=12,887'(MD)/TD=11,14201/D) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 2/19/2016 J • •14 Public Information Northstar Unit Well: NS-22 PROPOSED Last Completed: 1/27/2003 Ililrorp Alaska,LLCPTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm It' 20" Conductor 169/X-56/N/A N/A Surface 201' 20" 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' ,y 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 ;71,i 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 3/81 TUBING DETAIL WellLock 3-1/2" Tubing I 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' JEWELRY DETAIL 2 No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open I` Al 4 WELL INCLINATION DETAIL KOP@321' Max Hole Angle=43 deg.@ 11,377' 9-5/8" OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8-1/2"Hole 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole 17'4 ►%-� 7 TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI GENERAL WELL INFO API:50-029-23128-00-00 �L JI 11 Drilled&Completed by Nabors 33E-2/2/2003 12 Perf Add-7/9/2007 ' 13 Set TTP- 6/11/2010 1101 14 RTP-3/14/2015 r' 1 Ivishak Sands 4-1/2" TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 2/17/2016 • oFTit • S gwP��\�v7, THE STATE Alaska Oil and Gas • 7 OfA LAsKA Conservation COI11n11SSlOn 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o-1^\"' Main: 907.279.1433 ALAS Fax:Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 SCANNED MAR 0 32016 Re: Northstar Field,Northstar Oil Pool,NS-22 Permit to Drill Number: 202-223 Sundry Number: 316-154 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster �� Chair DATED this Z�}ay of February, 2016. RBDMS t.,vFEe 2 6 2016 A i ilio' • STATE OF ALASKA • FEB 2 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION IQ7S 2(Z4.--//t • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install WellLock Q- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: r i 4 JC Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ 202-223 . L.cAk_ 3.Address: Stratigraphic ❑ 6.API Number: ❑ Service 3800 Centerpoint Dr,Suite 1400 50-029-23128-00-00 - 7. If perforating: 8 Well Name and Number: — What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A. Will planned perforations require a spacing exception? Yes ❑ No ❑ NORTHSTAR UNIT NS-22 - 9.Property Designation(Lease Number): 10.Field/Pool(s): OCS Y-0181 - Northstar Field/Northstar Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,886' . 11,141' - 12,860' 11,121' 3,780 12,295' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2;13Cr80 12,303' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2"Bkr Lnr Top Pkr&7"x 5"Bkr ZXP Pkr 10,458MD/9,293TVD, 12,257MD/10664TVD, 12,307MD/10,702TVD and 1,142MD/ and 3-1/2"TRM-4E SSSV 1,127TVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 3/1/2016 Commencing Operations: OIL ❑✓ . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval Contact Taylor Wellman Email twellman(hilcorp.com Printed Name ike Dunn Title Operations Manager Signature Phone 777-8345 Date 2/19/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 ‘(-C — lS `f Plug Integrity ❑ BOP W_ Test ❑ Mechanical Integrity Test [ Location Clearance ❑ i Other. -/l c�prn� oat.J�r -i-e cc:,-for.1KCe c'lot.z,....- 1"11r"..4.. 4p,•. 1 3Q , G' Of4 /be rt.ktij ili t c-c Cils;e.y Post Initial Injection MIT Req'd? Yes ❑ No ❑ {i cz i;L i Spacing Exception Required? Yes ❑ No 2` Subsequent Form Required: 0-- 9 O`ja RBDMS tA. -3 6 2016 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: 2_L(/ /� Submit Form and Form 10-403 Re ised 11/2015 Approved application is vfci f2iq hi stmt.:of approval. Attachments in Duplicate DC7' -.telz -4 • • Repair SC Leak Well: NS-22 PTD: 202-223 • Hilcora Alaska.LLf API: 50-029-23128-00 Well Name: NS-22 API Number: 50-029-23128-00 Current Status: Online Rig: N/A Estimated Start Date: March 1, 2015 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 202-223 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Maximum Expected BHP: 5,124psi @ 11,100' TVD (Based on SBHPS on NS-15 11/12/15) Max. Anticipated Surface Pressure: 3,780psi (During well SI on 06/13/15) Brief Well Summary: NS-22 is a naturally flowing production well. The well was SI from June 2010—March 2015 due to a leak in the surface casing. During diagnostics in June 2010,the leak was identified at 4' below the OA valve during an MIT- OA w/diesel. In March 2015 the tubing plug was pulled,the well passed an MIT-IA to 2500psi, additional instrumentation was installed and the well was returned to production under Sundry#315-088 for a surface casing leak and has special operating conditions. The well has remained online since this time and has shown no signs of worsening of the leak. 06/06/10: NS reports leaking wellhead equipment below OA valve 06/07/10: MIT-OA Failed; diesel broach to surface confirming SC 06/11/10: Set PXN plug @ 12236' md, MIT-T Passed to 2500 psi, MIT-IA Passed to 2500 psi 06/26/10: Liquid leak rate pumping down OA"2.8 gpm @ 140 psi 06/27/10: SC leak found @ 4' 12/19/10: Operator reported 2-3 quarts of diesel leaked into the cellar 10/11/13:Tubing hanger void test Failed 10/15/13: Set two way check,tubing hanger void test Passed to 5000psi, change tree to dry hole tree, pull two way check. 03/12/15: MIT-IA Passed to 2500ps/ 03/13/15: Instrumentation installed, Sundry Approved and return well to production 02/01/16: To date the well has burped a total volume of 71.5gals, in large part due to high ambient temps in the summer months. OA Status: Closed shoe. During initial completion,the OA was down-squeezed with 33bbls of cement followed by 190bbls of water and diesel. The estimated TOC is at^'3482' and or—220'above the SC shoe. SC Leak Depth/Rate: Leak was determined to be 4' below the OA valve,or-1.5' below the cellar floor.This was identified by fluid packing the OA then pumping N2 down the OA while taking fluid returns from the conductor. Once gas returns were observed, the OA pressure was bled down and a plumb bob was put through the OA casing valve until a fluid level was found. A subsequent leak rate was observed at 2.8 gpm on 6/26/10 while pumping diesel down the OA at 140 psi.Two weeks prior OA pressured to 1200 psi with pressure losses of only 90 psi/15 min. • • Repair SC Leak Well: NS-22 PTD: 202-223 Iiilcorp Alaska.LL) API: 50-029-23128-00 Objective: To mitigate flow of hydrocarbons to surface through the SCxConductor annulus. Timing: Scheduled for late February 2016. The current timing for repair under Sundry#315-088 is for the well to be repaired or shut in on February 26, 2016.The proposed procedure would allow the well to remain online until the scheduled repair can be conducted or an alternative repair option (excavation & external patch) can be completed in late ice road season (approx.April 1, 2016). The timing is based on the following reasoning for the excavation repair: 1. Minimal amount of water influxing into the excavation. The frozen sea should provide the minimal amount of water to be handled while the excavation is in place based on best practices shared from other operators. 2. Extreme temperatures. The repair time in late ice road season vs. early ice road season will allow for avoiding the worst months in terms of extreme cold for exposure to personnel. Procedure: 1. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. 10 gal of RG-2014 has been pumped into the conductor via the cementing port on 05/02/09. Use of a citrus based hand cleaner is the recommended solvent for final cleaning of the RG- 2401 from the SC&conductor walls. 4., 2. Bleed OA pressures to 0 psi. ` 3. Drill holes in the upper section of the 20" surface casing w/ non-sparking bit and mag drill. a. Holes will be^'2" diameter, circumferential and evenly spaced around the conductor. b. The conductor is 20", 169#,X-56, ID=18.376", Burst=3910psi, Collapse=2500psi. 4. Clean conductor and flush until free of hydrocarbons and SCxConductor annulus is as clean as possible. a. Use of a steam wand washing the annulus with water and solvent will be conducted. 5. Place heater in wellhouse circulating air through the conductor to dry it out of any fluids. 6. Use a boroscope down the conductor to inspect 13-3/8" surface casing for corrosion and leak site. 7. Have UT thickness testing conducted around the upper exposed portion of the 13-3/8" SC to check for possible drilling damage. 8. Contingency: If additional room for UT inspection to be completed is needed, use saw to cut between drilled holes to widen inspection windows. Possible use of nitrogen purge into the OA w/ N2 bottles. This will be determined by how well the conductor can be cleaned and remain free of any possible flammable materials. 9. Contingency: If there is not a hard bottom in the conductor add in steps for a top job to be pumped. 10. Fill the well cellar with water up to a level just below the cement return port. This will act as an additional temperature sink to absorb heat while the treatment is curing. 11. Mix WeIlLock as per recommended volumes, concentration, and pumping procedure to place a volume (minimum of 6.5gal or 1') into the lower portion of the conductor. a. The SCxConductor volume=0.155bpf or 6.5gpf b. Treatment volume will be approx. 11 gal &will come up to just below the cementing port. 12. Allow WeIlLock to cure for 2-3 days. a. Monitor temperature during curing phase. 13. Conduct an KIT-OA to 375psi w/diesel. k a. Pressure Testing Justification: Leak rate observed is ^'2.8gpm at 140psi and has demonstrated rleaking diesel into the cellar at 5-10psi on the OA. OA pressures prior to SC leak development / ( fluctuated between 0-300 psi during normal operations. /out (7 .) 1--/�� i. �V U T c n. /^1c ci' • • Nortll:hstarNS-22 Unit . 11 We SCHEMATIC Last Completed: 1/27/2003 flacon)Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.517 BF Bev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 201' 20' (1 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 14 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' (\( 133 - �� TUBING DETAIL 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' Leak @ Approx.4' JEWELRY DETAIL 2', No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" / 8 12,284' 3-1/2"HES X Nipple,ID=2.813" msµ'+ 98 12,295 33--11//22,',' -1/2"HES XN Nipple,ID=2.75"(12,307'ELM) ' 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open I Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open _� 4 WELL INCLINATION DETAIL • n' WELL @ 321' Max Hole Angle=43 deg.@ 11,377' 9-5/8" A OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole I5 7" " " " 6 4-1/2" 100360 sxsx ClassClass"GG"inin 6-1/881/2"Hole'" ' 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"SKS! Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 L j 11 Drilled&Completed by Nabors 33E-2/2/2003 ■i 12 Perf Add-7/9/2007 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"• • Iv steak Sands 4-1/2" TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 2/19/2016 Northstar Unit . . 14 • , Well: NS-22 PROPOSED Last Completed: 1/27/2003 Ailcorp Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 201' 20" * 13 3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' Nq9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 ^=1 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' !! 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 13-3/3 • TUBING DETAIL WeIlLock 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' � f JEWELRY DETAIL 2 No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open I` 4 WELL INCLINATION DETAIL ml KOP@321' Max Hole Angle=43 deg.@ 11,377' 15/8" A • OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8-1/2"Hole 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole 17 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 L J 11 Drilled&Completed by Nabors 33E-2/2/2003 12 Perf Add 7/9/2007 ■ 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"• • r Ivishak Sands 4-1/2" } TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 2/17/2016 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Return to Production rA Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Tree Swap Pull Plug IN 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory❑ 202-223 3.Address: Stratigraphic Service❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23128-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: OCS Y-0181 NORTHSTAR UNIT NS-22 1 Y "' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Northstar Field/ Northstar Oil FEB 17 2016 11.Present Well Condition Summary: Total Depth measured 12,887 feet Plugs measured N/A feet true vertical 11,141 feet Junk measured N/A feet 10,458, 12,257& Effective Depth measured 12,860 feet Packer measured 12,307 feet 9,293, 10,664& true vertical 11,121 feet true vertical 10,702 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED MAR 0 8 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13Cr80/Vann-Ace 12,303' 10,699' 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2" 10,458MD/9,293TVD, Bkr Lnr Top Pkr&7" 12,257MD/10,664TVD, Packers and SSSV(type,measured and true vertical depth) x 5"Bkr ZXP Pk 3-1/2"TRM-4E SSSV 12,307MD/10,702TVD 1,142MD/1,127TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 484 164 Subsequent to operation: 852 39,460 112 1,021 797 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-088 Contact Taylor Wellman ira" Email twellman c(�hilcorp.com Printed Name Bo York Title Operations Engineer Signature .17.......%."---------- Phone 777-8345 Date 2/17/2016 Form 10-404 Revised 5/2015 76- 2-r5-rt Submit Original Only 76- .2 RBDMSa � 'LL f€ is zOl+' 9vp Vv"',", J H woe.pZ c i s • •w Northstar Unit 14 Well: NS-22 • SCHEMATIC Last Completed: 1/27/2003 IHilcorp Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BF Elev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 201' 20' 13 3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' 9-5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 a 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' ' 4-1/2" Liner 12.6/13Cr80/VAM-ACE 3.958 12,303' 12,887' 13-3/8" TUBING DETAIL 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' JEWELRY DETAIL 2 No Depth Item [ 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch s 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" t ! 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) • 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 44/2"X0,10=2.992" 11 12,307' 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" , 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" , F' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1 e' Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open IIvishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open F 4 WELL INCLINATION DETAIL KOP @ 321' Max Hole Angle=43 deg.@ 11,377' 9-5/g ` OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8-1/2"Hole 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole st rte. 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 1 C1 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 L J 11 Drilled&Completed by Nabors 33E-2/2/2003 J■ 12 Perf Add-7/9/2007 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"• }Ivishak Sands 4]J2"i TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 4/30/2015 • Hilcorp Alaska, LLC 11aAstt,LI( Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date NS-22 50-029-23128-00-00 202-223 3/4/2015 3/13/2015 Daily Operations: 3/4/15-Wednesday Verify tubing pressure=Opsi(SSSV holding).Close master valve. Break bolting between master and upper master valves. Clean and inspect ring grooves.Install upper tree assembly.Torque to Vetco Gray spec.Pressure test upper tree to 300psi low/5000psi high. 3/6/15-Friday RU triplex to IA.Pressure test IA.MIT-IA to 2,500psi-Pass.Initial T/I/0=411/2,545/38,15 min T/I/0 423/2,509/33(lost 36psi),30 min T/I/0=425/2481 30 tlostl$psi).RU slickline unit. Pressure test lubricator to 300psi low/4,200psi high. 1" RIH w/2.85"centralizer,hang up @ 950',and POOH. RIH w/2.5"JDC pulling tool,set down at 2,800',3,159',and 3,409'. lPC. POOH and bump up tools.Wire break,recover tools from tree. 3/7/15-Saturday RU slickline unit and pressure test lubricator to 300psi low/4,200psi high.RIH 1.5"sample bailer,work thru tight spots and break thru at 3,528'.Tag plug prong at 12,240'and POOH.RIH w/2.5" bailer,work to 2,898'and POOH.RIH,latch P- Prong at 12,295'MD,POOH.Secure well and lay down for night. 3/10/15-Tuesday RU slickline unit.Plug equalized and tubing pressure=900psi.Pressure test to 100psi low/1,000psi high.RIH w/3.5" GJDC and pull plug body from 12,295'md.Job complete. 3/13/15-Sunday [NS-22 return to production and cellar sump pump configuration install STATE OF ALASKA �,/�D AL __KA OIL AND GAS CONSERVATION COME. MON r 3 REPORT OF SUNDRY WELL OPERATIONS �` 0 20 � 1 Operations Abandon U Repair Well LI Plug Perforations U Perforate U Othet( eQwap/Pull Plug Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver U Time Extension U Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development D Exploratory ❑ 202-223 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-23128-00-00 7 Property Designation(Lease Number): 8.Well Name and Number: OCS Y-0181 NORTHSTAR UNIT NS-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Northstar Field/Northstar Oil 11.Present Well Condition Summary. Total Depth measured 12,866 feet Plugs measured N/A feet true vertical 11,141 feet Junk measured N/A feet 10,458, 12,257& Effective Depth measured 12,860 feet Packer measured 12,307 feet 9,293, 10,664& true vertical 11,121 feet true vertical 10,702 feet Casing Length Size MD ND Burst Collapse Structural Conductor 201' 20" 201' 201' Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation depth Measured depth See Attached E SchematicbI'�N� ^ >^ 1, �r�A 01 1 8 l_ ,, True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/13Cr80/Vam-Ace 12,303' 10,699' 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2" 10,458MD/9,293ND, Bkr Lnr Top Pkr&7" 12,257MD/10,664ND, Packers and SSSV(type,measured and true vertical depth) x 5"Bkr ZXP Pk 3-1/2"TRM-4E SSSV 12,307MD/10,702ND 1,142MD/1,127TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 484 164 Subsequent to operation: 1,449 41,957' 17 721 795 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-088 Contact Taylor Wellman Email twellman Cl hiIcorp.com Pnnted Name Tay.r W-Oman Title Operations Engineer Signature Phone 907-777-8449 Date 4/30/2015 corm 1U-4U4 a'Rum Z irTL 5/14i/5- At,M,(45----- RBDMSjc owl(VJJnry Northstar Unit Well: NS-22 14 . SCHEMATIC Last Completed: 1/27/2003 Hilcorp Alaska,LLC PTD: 202-223 CASING DETAIL KBE=56.51'/BFElev=40.2'(CB 15.9) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor - 169/X-56/N/A N/A Surface 201' [ I 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,707' �_ 9 5/8" Production 47/L-80/BTM-C 8.681 Surface 10,680 r= 1 7" Liner 26/L-80/Hydril 521 6.276 10,458' 12,469' 4-1/2" Liner 12.6/1TUBING 3Cr80I/GAM-ACE 3.958 12,303' 12,887' 13-3/8" DETAIL 3-1/2" Tubing 9.2/13Cr80/VAM-ACE 2.992 Surface 12,303' JEWELRY DETAIL 2 No Depth Item 1 1,142' 3-1/2"TRM-4E SSSV w/ID=2.813" 2 5,032' SMOR GLM w/Dummy Valve&BK Latch 3 3 5,910' SMOR GLM w/Dummy Valve&BK Latch 4 10,458' 9-5/8"X 7"Baker ZXP LTP w/Flex Lock Hgr,ID=6.20" 5 12,211' 3-1/2"Fiber Optic Transducer(12,223'ELM) 6 12,236' 3-1/2"HES X Nipple,ID=3.813" 7 12,257' _ 7"X 3-1/2"Baker Liner Top Packer,ID=2.875" 8 12,284' _ 3-1/2"HES X Nipple,ID=2.813" 9 12,295 3-1/2"HES XN Nipple,ID=2.75"(12,307'ELM) 10 12,306' 3-1/2"X 4-1/2"XO,ID=2.992" 11 12,307' _ 7"X 5"Baker LTP 12 12,311' 4-1/2"Self Aligning WLEG,ID=3.850" 13 12,329' 7"X 5"Baker Liner Hanger 14 12,339' 5'X 4-1/2"XO,ID=3.958" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Ivishak 12,760' 12,818' 11,045' 11,089' 58 2/2/2003 Open Ivishak 12,833' 12,853' 11,101' 11,116' 20 7/9/2007 Open ilI 4 WELL INCLINATION DETAIL JKOP @ 321' Max Hole Angle=43 deg.@ 11,377' 9-5/8" OPEN HOLE/CEMENT DETAIL p 1 20" Driven 13-3/8" 615 sx PF"L",474 sx Class"G"in 16"Hole 9-5/8" 720 sx Econolite,565 sx Class"G"in 12-1/4"Hole 5 7" 360 sx Class"G"in 8-1/2"Hole 6 4-1/2" 100 sx Class"G"in 6-1/8"Hole 13 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"SKSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 9 GENERAL WELL INFO 10 API:50-029-23128-00-00 L as J 11 Drilled&Completed by Nabors 33E-2/2/2003 12 Perf Add-7/9/2007 j IIP�; 13 Set TTP- 6/11/2010 14 RTP-3/14/2015 7"• 6 EiE}Iishacsa1as Sands 4-1/2'1 II TD=12,887'(MD)/TD=11,142(TVD) PBTD=12,860'ELM(MD)/PBTD=11,121'(TVD) Reviseded By:TDF 4/30/2015 Hilcorp Alaska, LLC ,:,_k:,. Weekly Operations Summary Well Name API Number _Well Permit Number Start Date End Date NS-22 50-029-23128-00-00 202-223 3/4/2015 3/13/2015 Daily Operations: 3/4/15-Wednesday Verify tubing pressure=Opsi (SSSV holding). Close master valve. Break bolting between master and upper master valves. Clean and inspect ring grooves. Install upper tree assembly.Torque to Vetco Gray spec. Pressure test upper tree to 300psi low/5000psi high. 3/6/15-Friday RU triplex to IA. Pressure test IA. MIT-IA to 2,500psi-Pass. Initial T/I/0=411/2,545/38, 15 min T/I/0=423/2,509/33 (lost 36psi),30 min T/I/0=425/2481/30(lost 28psi). RU slickline unit. Pressure test lubricator to 300psi low/4,200psi high. RIH w/2.85"centralizer, hang up @ 950',and POOH. RIH w/2.5"JDC pulling tool,set down at 2,800',3,159',and 3,409'. POOH and bump up tools.Wire break, recover tools from tree. 3/7/15-Saturday RU slickline unit and pressure test lubricator to 300psi low/4,200psi high. RIH 1.5"sample bailer,work thru tight spots and break thru at 3,528'.Tag plug prong at 12,240'and POOH. RIH w/2.5" bailer,work to 2,898'and POOH. RIH, latch P- Prong at 12,295' MD, POOH.Secure well and lay down for night. 3/10/15-Tuesday RU slickline unit. Plug equalized and tubing pressure=900psi. Pressure test to 100psi low/1,000psi high. RIH w/3.5" JDC and pull plug body from 12,295'md.Job complete. 3/13/15-Sunday NS-22 return to production and cellar sump pump configuration install F 7, Alaska Oil and Gas • (<0 1y/, sTHE STATE-s�i � ofALAsKA Conservation Commission 2 333 West Seventh Avenue .14e167- 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASFax 907.276.7542 M Ak www.aogcc.alaska.gov Taylor Wellman SCO Operations Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 a 0 Anchorage, AK 99503 Re: Northstar Field, Northstar Oil Pool,NS-22 Sundry Number: 315-088 Dear Mr. Wellman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, °c9 Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2015 Encl. . 1 ' RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 7 2015 APPLICATION FOR SUNDRY APPROVALS �Q�iGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing 0 Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: Tree Swap/Pull Plug ❑, • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. RGtv✓`-' ', Hilcorp Alaska,LLC • Exploratory ❑ Development ❑ 202-223 • t0 Pivdvc hey. 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23128-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.458A Will planned perforations require a spacing exception? Yes ❑ No ❑., NORTHSTAR UNIT NS-22 9.Property Designation(Lease Number): 10.Field/Pool(s): OCS Y-0181 • Northstar Field/Northstar Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,886' 11,141' • 12,860' 11,121' 12,295' N/A Casing Length Size MD ND Burst Collapse Conductor 201' 20" 201' 201' Surface 3,707' 13-3/8" 3,707' 3,413' 5,020psi 2,260psi Intermediate 10,680' 9-5/8" 10,680' 9,471' 6,870psi 4,760psi Intermediate 2,011' 7" 12,469' 10,825' 7,240psi 5,410psi Liner 584' 4-1/2" 12,887' 11,142' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,760-12,818,12,833-12,853 11,405-11,089,11,101-11,116 &12,240-12,853 &10,652-11,116 3-1/2" 9.2/13Cr80 12,311' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 9-5/8"x 7"Bkr Lnr Top Pkr,7"x 3-1/2"Bkr Lnr Top Pkr&7"x 5"Bkr ZAP Pkr 10,458MD/9,293ND, 12,257MD/10664ND,12,307MD/10,702ND and 1,142MD/ and 3-1/2"TRM-4E SSSV 1,127ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic p Development Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/23/2015 • Oil j• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature ------5741"1/4-1/ Phone 777-8449 Date 2/16/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\S — 0�5 Y Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Ca vel cutis Ov2/ ,S 6F a-pp VQR �/� ChCG .. if/VC nth 5YLa✓ lJkxif IV - ZZ (Pro 20Z- 2Z3) ! 5c.r,dry 3 i 5.-- 0gC. e ondf I 'I- f a � e" c.vzdry -1-pie`-017. -i " Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: / Q — 4 0 9- APPROVED BY Z ( � -1 1 S Approved by:, 01 S ONER THE COMMISSION Date: I � autsi rorm ana Form 10-403(Revised 10/2012) A a� � ��iiiLad2 months tripthe date of approval. achments'Duplicate vrt. Z/26/'5 RRDMSJ MAR - 7 2015- �71-i1- 0 L /I- 's • Northstar Unit NS-22(PTD 202-223):SUNDRY 315-088 CONDITIONS FOR SUNDRY APPROVAL 1. Approved surface casing(SC) leak repair must be completed within a year. 2. If a rig is mobilized on the island in the next year,the SC leak in this well must be repaired. 3. Must be equipped with shutdown on IA and OA to be tested as part of the well safety valve system Set point for the IA is 1500 psi.Set point for the OA is 50 psi. 4. LEL detector to be installed in the well house mounted to the tree directly above the well cellar. The LEL alarm points to be set at 40%. 5. Testing of additional safety equipment(LEL alarm; IA/OA shut downs will be a part of the SVS testing) 6. Monthly reporting required including TIO plot. 7. Bleed frequency limited to twice weekly. All pressure bleeds will be to containment. 8. If the well is required to be shut-in for any reason,a deep plug must be set to isolate the production zone from the wellbore. 9. Maintain sign on the well and information in the well house: Sign to read"Waived well-SC- leak".A one page summary describing the well condition and waiver stipulations must be maintained in the well house and clearly identified. 10. Gas lift not allowed. 11. Notify AOGCC if conditions appear to deteriorate such as annuli pressures tracking.Any diagnostics for anomalous annulus pressure related conditions must be communicated to AOGCC. Tree Install & Pull Plug Well: NS-22 . , , PTD: 202-223 llilcorp Alaska,LL API: 50-029-23128-00 Well Name: NS-22 API Number: 50-029-23128-00 Current Status: SI —Surface Casing Leak ✓ Rig: Vetco Gray&SLB SL Estimated Start Date: February 21, 2015 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 2022230 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Current Bottom Hole Pressure: 4,972psi @ 11,100' TVD (Based on SBHPS on NS-28 9/22/14) Maximum Expected BHP: 4,972psi @ 11,100' TVD (Based on SBHPS on NS-28 9/22/14) Max. Anticipated Surface Pressure: 3,900psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: NS-22 is a naturally flowing production well that has been shut in since June 2010. The well was SI when a surface casing leak at 4' below the OA valve was confirmed during a diagnostic MIT-OA with diesel. The well has been secured with a tubing plug and has remained shut in. 06/06/10: NS reports leaking wellhead equipment below OA valve 06/07/10: MIT-OA Failed; diesel broach to surface confirming SC 06/11/10: Set PXN plug @ 12236' md, MIT-T Passed to 2500 psi, MIT-IA Passed to 2500 psi 06/26/10: Liquid leak rate pumping down OA^'2.8 gpm @ 140 psi 06/27/10: SC leak found @ 4' 12/19/10: Operator reported 2-3 quarts of diesel leaked into the cellar 10/11/13:Tubing hanger void test Failed 10/15/13: Set two way check,tubing hanger void test Passed to 5000psi,change tree to dry hole tree, pull two way check. Hilcorp intends to return this well to production while managing the SC leak with the following mitigations in place: 1. Pass an internal MIT-IA to 2,500 psi demonstrating two competent barriers. 2. Pressure based shutdowns equipped to the IA and OA. Set points are suggested to be 1500psi/50psi respectively. 3. LEL alarm set inside the wellhouse that activate alarms to the control room. 4. Continuous monitoring and recording of tubing and annulus pressures with software OA pressure alarms. 5. Daily monitoring of the sealed metal cellar during operator well inspections. 6. Air operated automatic sump pump has been installed to give warning of fluids in cellar and pump them to a nearby tote (similar to NS-15, NS-25 and NS-29.) Tree Install & Pull Plug Well: NS-22 • PTD: 202-223 Hilearn Alaska.LL API: 50-029-23128-00 Objective: Prepare the well for return to production through the following actions: confirm barriers in the well to be able to change the tree from a dry hole tree to a full production tree, confirm integrity in the well, remove plug from the well and return to production. Procedure: Operations 1. Open well and conduct a negative test of the TRSSSV(currently shut). a. Passing criteria: Opsi buildup for 30 min. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. a. Note: The well was loaded with 175bbIs of seawater and 17bbls of diesel (1120' md) on top of a PXN plug set at 12295'. An MIT-T passed on 6/11/10 and has remained shut in since this time. With Opsi on the tubing,the plug will be—165psi underbalanced. 2. MIT-IA to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. 3. Bleed IA to Opsi and RD test equipment. Tree&Wellhead Work 1. Verify that tubing and IA pressures have been bled to 0 psi. 2. Close the master valve. 3. Pressure test against the master valve to 300psi low and 5000psi high. 4. Unbolt and remove the upper dry hole tree. 5. Install upper tree as per the attached diagram. 6. Pressure test the upper tree assembly to 5000psi. 7. Close the Swab and SSV. RD from the well. Slickline Work 8. Pressure test to 300psi low and 4200psi high. 9. RIH and equalize plug. Monitor for signs of equalization prior to pulling plug body. 10. Pull 3-1/2" PXN Plug from 12295' md. 11. RDMO. Attachments: As-built Well Schematic and Deviation Survey,Tree&Wellhead Diagrams. NS-22 13 5/8 X4%tubing hanger/W 4"BPV profile 04 0 xsow S N \yet$a e I 1-10 65QP ‘Se. CP.1 a,.,4 NO v41o1 :le Glad(OP t'ee � Ci ap �C' sCA rn U ��s)A% �4- .., . a K4Y fY_ Y.{ fill 1E 135/8 SM X 13 5/8 SM I1 no 011111 p sill 1 1-1- 1 21/16 gray HWO valve Tubing spool i .< ,A 1 III I RI r Y.. Iii I II I1��v�-11` 1141. rr'; 4/ le-1.' 21/16 gray HWO valve 13 5/8 9 5/8 101 4 1/2 NS-22 Proposed 13 5/8 X 434 Hanger 4" profile ■ • 5 1/8"Gray 6500PSI Swab valve - (6 0 000 —'rot nip —771 e 7 51/B"Gray s Valve,Wing, B keractuator 5 1/8"Gray 6500PSI valve SSV Baker actuates ■ —7-on rrniTT 5 1/8"Gray 6500PSI Master valve ', 0 4114. bSCP 5 r.,.. �....�.. ,�S'��,t,Q`et 8 - 11 o5M5135/85M // .pool (- •11111 Noti I I/E .` )j P 2 1/16 gray HWO valve vs d 21/16 gray HWO valve 13 5/8 J 9 5/8 4 1/2 TREE_, ABB-VG!5-1/8"F ° SY NOTES:WELL REQUIRES A SSSV. WELLHEAD= ABB-VGI 13-5/8"MULTIBOWL.. a NS22 S22 *' 2"CHROME TBG&4-1/2"CHROME LNR*** r ACTUATOR= BAKER \e/01/4' NOTE: BOEMREWELL KB.ELEV= 56.51' BF.ELEV= 40.2'(CB 15.9') I - 1142' —13-1/2"TRM-4E SSSV,ID=2.813" KOP= 321' I Q Max Angle= 43°@ 11377' Datum MD= 12114' Datum TVD= 10500'SS 13-3/8"CSG,68#,L-80 BTC,ID=12.415" 1 3707' IA GAS LIFT MANDRELS ST MD _ TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =2.75" @ 12295' L 1 5032 4563 29 SMOR DMY BK 0 02/03/03 3-1/2" XN NIPPLE 2 5910 5335 28 SMOR DMY BK 0 01/31/03 TOP OF 7"LNR —1 10458' , —I 10458' -jI9-5/8"X 7"BKR ZXP LNR TOP PKR I w/FLEX LOCK HGR,ID=6.20" 9-5/8"CSG,47#,L-80 BTM-C, ID=8.681" 1 10680' , 12211' 3-1/2"FIBER OPTIC TRANSDUCER I (12223'ELM D) ' ' 12236' —13-1/2"HES X NIP,ID=2.813" XX1 12257' —17"X 3-1/2"BKR LNR TOP PKR,ID=2.875" ' 12284' I3-1/2"HES X NIP,ID=2.813" i-------- 12295' 4 2.81"PXN PLUG(06/11/10) 12295' H 3-1/2"HES XN NIP, ID=2.75"(12307'ELM D) TOP OF 4-1/2"LNR — 12303' 12306' 3-1/2"X 4-1/2"XO,ID=2.992" 3-1/2"TBG,9.2#/ft,13C VAM-ACE, -1 12311' H—/ i 12307' 1 7"X 5"BKR ZXP LTP,ID=?" 0.0087 bpf,ID=2.992" -I-. ,---- 12311' 1-1_4-1/2"SELF ALIGNING WLEG,ID=3.85" I 7"LNR,26#,L-80 HY DRIL 521, H 12469' 12329' 17"X 5"BKR LNR HGR,ID=?" 0383 bpf,ID=6.276" 12339' H 5"X 4-1/2"XO, ID=3.958" PERFORATION SUMMARY REF LOG: GR/CCL 01/24/03 ANGLE AT TOP PERF: 40 @ 12760' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL(MD) Opn/Sqz DATE 2-1/4" 6 12760-12818 0 02/02/03 2-1/4" 6 12833-12853 0 07/09/07 PBTD 1860 elm 4-1/2"LNR, 12.6#,13CR VAM-ACE, -I 12887' Q 0.0152 bpf,ID=3.958" �<xXXxXX1, DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 01/27/03 N33E FINAL COMPLETION 06/29/08 WRR/PJC DRAWING CORRECTIONS WELL: NS22 02/07/03 MJF ADD PERFS 01/05/10 TA/PJC XN ELMD DEPTH CORRECTION PERMIT No: 2022230 11/04/05 BJM NEW FORMAT: p c.,1.,,, 06/18/10 RCT/SV SET TTP(06/11/10) API No: 50-029-23128-00 02/15/06 RAC/PAG SAFETY NOTE-MMS WELL 10/26/10 BSE/PJC SFTY NOTE UPDATE(10/08/10) SEC 11,T13N,R13E, 1260'FSL&647'FEL 07/22/07 RMH/PJC ADPERFS(07/09/07) 02/17/11. MB/JMD,ADDED SSSV SAFETY NOTE Hilcorp Alaska, LLC 11/27/07 WRR/JC WELLHD/LOCATION CORRECTIONS Tree Install & Pull Plug Well: NS-22 PTD: 202-223 ilii,.,,,.,, API: 50-029-23128-00 Objective: Prepare the well for return to production through the following actions: confirm barriers in the well to be able to change the tree from a dry hole tree to a full production tree, confirm integrity in the well, remove plug from the well and return to production. Procedure: Operations 1. MIT-T to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. a. Note: The well was loaded with 175bbIs of seawater and 17bbls of diesel (1120' md). An MIT-T passed on 6/11/10 and has remained shut in since this time. With Opsi on the tubing, the plug will be —165psi underbalanced. 2. MIT-IA to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. 3. Bleed IA to Opsi and RD test equipment. Tree &Wellhead Work 1. Verify that tubing and IA pressures have been bled to 0 psi. 2. Close the master valve. sup ER sElp D 3. Pressure test against the master valve to 300psi low and 5000psi high. 4. Unbolt and remove the upper dry hole tree. 5. Install upper tree as per the attached diagram. 6. Pressure test the upper tree assembly to 5000psi. 7. Close the Swab and SSV. RD from the well. Slickline Work 8. Pressure test to 300psi low and 4200psi high. 9. RIH and equalize plug. Monitor for signs of equalization prior to pulling plug body. 10. Pull 3-1/2" PXN Plug from 12295' md. 11. RDMO. Attachments: As-built Well Schematic and Deviation Survey,Tree &Wellhead Diagrams. _suPERSSVED O F SEAN PARNELL, GOVERNOR ALASKA O II. A" GAS 333 W. 7th AVENUE, SUITE 100 DII CONSERVATION CO USSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 AMAD NOV 0 6 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS22 Sundry Number: 310 -366 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0-1� Daniel T. Seamount, Jr. cc�� Chair DATED this I day of November, 2010. Encl. STATE OF ALASKA ' ALASOSIL AND GAS CONSERVATION COMMISSIOI• 11 Lt' to jA0 APPLICATION FOR SUNDRY APPROVALS i t 20 AAC 25.280 1. Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate[] Re -enter Suspended Well ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate[] Other - Specify: Surface Casino Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑, Exploratory ❑ 202-2230- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99519 -6612 50- 029 - 23128- 00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑l NS22 9. Property Designation (Lease Number): 10. Field / Pool(s): OCSY -0181 1 NORTHSTAR Field / NORTHSTAR OIL Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12887 11141.75 , 12860 11121 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3663 13 -3/8" 68# L -80 44 3707 44 3413 4930 2270 Intermediate Production 10638 9 -5/8" 47# L -80 42 10680 42 9471 6870 4760 Liner 2012 7'26# L -80 10457 12469 9292.55 10825 7240 5410 Liner 584 4 -1/2" 12.6# 13CR80 12303 12887 10699 11142 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - 3 -1/2" 9.2# 13Cr80 40-12303 Packers and SSSV TVDe: 3 -1/2" TRM-4E Packers and SSSV MD and TVD (ft): 1127 1113 9- 5/8 "X7' BKR ZXP LNR TOP PKR 10457 9293 7'X3 -1/2" BKR LNR TOP PKR 12257 10664 7'X5" BKR ZXP LTP 12303 10699 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2009 Oil ❑� - Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title Production Engineer Signature Phone Date 564 -4660 10/27/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY (n Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: t O +� C T 2 8 20,10 Subsequent Form Required: ! U /Q , &NW 'Cons.Gow ian APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: f ? �`1� / 0 RB MS NOV 0 ORIGINAL Form 10 -403 Revised 07/2009 Submit in Duplicate NS22 202 -223 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS22 2/2/03 PER 12,760. 12,818. 11,045.17 11,089.32 NS22 719/07 APF 12,833. 12,853. 11,100.71 11,115.91 NS22 6/11/10 BPS 12,240. 12,853. 10,651.56 11,115.91 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • F No portion of the below4krk should be performed w /out firsOaking time to ensure by No Accidents, No harm to People, and No damage to the Environment 0 To: Jerry Bixby /Clark Olsen — Wireline Operations Supervisor Oct 27, 2010 From: Mark Sauve — Northstar Production Engineer 336 -6128 (w) 748 -2865 (c) 336 -6128 (h) Subject: NS22 Brinker Platelet OA Treatment Est. AFE NSFLDWL22 Est. 10R: NIA Type IOR PR N DSWL AFE Job Description F N/A NS22 NSFLDWL22 Pump Gelled Diesel with B rinker Platel Balls down OA S N/A NS22 NSFLDWL22 Pull plug in tubing tailpipe Current Status: Producer Last Test: 5/7/10: 837 BOPD, 990 BWPD, 37,401 MMCFPD Max Inclination: 43 at 11,377 md; 40 at Perfs Max Dog Leg: 4.6 deg /100' at 321' and Minimum ID: 2.75" @ 12,295' md, 3.5" XN Nipple Last TD tag: 12116/09: Drift w/ 2.5" Dummy gun to 12,865' MD (corrected) Last Downhole Op: 6111/10: Set PX plug and prong in NX nipple @ 12,295' MD Latest H2S value: None anticipated BHP: 5,092 psi @ 11,100 ft ss, 5/3/08 NS22 is a 2003 Northstar development well. It has 3 %Z" Chrome tubing and a 4'h" Chrome liner. Recent well integrity troubleshooting has indicated the presence of a leak from the OA to the surface conductor. The well has been secured downhole and officially designated as "inoperable ". Recent diagnostic work has established the OA leak rate at 2.8 gallons /minute at 140 psig and determined th OA leak dept to b ap 48" inches below the annular valve. Objective: Seal off the leak from the OA to the surface casing and return the well to operable status. Proceedure: 1. Ensure a working heater is placed near wellhouse with trunk directed at the conductor flutes at least 48 hours ahead of job start. 2. Hold PJSMs. Monitor and record all TWO pressures throughout all stages of the job. 3. MIRU up pumping unit with Platelet Injection Manifold to OA companion valve. Have super sucker unit on location to vacuum out fluid from cellar as needed during job. No portion of the beloAork should be performed w /out firflaking time to ensure No Accidents, No harm to People, and No damage to the Environment 4. Mix up gelled diesel in pumping unit and test rheology as per design specs. 5. Pressure test hardline with diesel to 2500 psi. Bleed back pressure when done. 6. Establish circulation down OA into cellar using neat diesel and repeat liquid leak rate test perfomed in June to ensure leak is still present and validate estimated hole size. Vacuum out returns in cellar as necessary. 7. Establish circulation down OA into cellar using gelled diesel and attempt to establish leak rate similar to that performed with neat diesel. Vacuum out returns in cellar as necessary. 8. Once circulation has been established /confirmed shut dowm pumping and bleed system back to zero. Double block isolate the injection tee and confirm zero psi on piping. Remove injection tee cap, deploy the Brinker Platelets into the tee and re- install the cap. 9. Open the injection manifold valves and re- establish circulation down the OA, transporting platelets down the OA to the leak site. 10. Once indications of a seal are noted continue pressuring the OA to 2000 psi with diesel to fully set the platelets. 11. In the event of a partial seal or no seal being achieved, the resultant leak size will be recalculated using pressure & rate data to place further platelet batches repeating ' steps 7 -10. 12.Once a seal has been achieved bleed OA pressure to 200 psi. Vacuum out all returns from the cellar. 13. RDMO pumping unit. 14. Install tag on OA companion valve stating OA has been liquid packed. Formally notify operations of the well condition and the need to carefully monitor OA pressure during start-up. 15. Ensure an "operating pressure" sign has been placed on the OA valve to remind Northstar operators of the need to maintain pressurs on the OA from this point onwards. 16. Notify well integrity group of the successful treatment and that the well can now be officially evaluated for re- classification as an "operable" well. No portion of the belowoork should be performed w /out firstaking time to ensure No Accidents, No harm to People, and No damage to the Environment Slickline Proceedure (post- fullbore) NOTE: Do not execute this part of the procedure until receiving explicit approval from the Well Integrity Coordinator returning NS22 to "operable" status. 17. MIRU slickline unit. Hold PJSM. 18. MU BHA for recovery of PX prong. RIH and pull same. Note any change in WHP that would indicate the plug has equalized. 19. MU BHA for pulling plug body. RIH and pull same. 20. Once plug body has been successfully recovered RDMO slickline unit. 21. Notify operations that well is available for POP. Procedure Contacts: Mark Sauve WK: 564 -4660 HM: 336 -6128 Cell: 748 -2865 I No portion of the belowqtrk should be performed w /out firmaking time to ensure No Accidents, No harm to People, and No damage to the Environment TFSE = W MULT in B 901 llii1E 7Bfi ��111t�1 YMDMD7E� "' 03 i-1 WYELLHEAD N S22 11 ,IR. ACFUA7I7R LF_F3LY. 4&71M ffi 3i�2"TRli£' l,9).28i3 xis i jum Ltaten w. 121 iA L unTYU i5OW 13-W cam. sale, L»ea ffm;a =12,4 w GASLAFTIANURELS Unlmum D : 27V MW Law lrr XN NI pu z saID Sw a Ow aFt 0 0 TOEr "FxrI RzwLJIRTC "IR wrFM U=HW o .am s w CM Co.I HIU-Q D ..&=- 3-idr Fitt OM WthIIIISMIM c a= "Q aii2'"F� D.� r %3.U"B(RLNRTOPP R 9) .2876" 3•it2" Fly x NP, FD. 2sO°' 28i "F9vJP1JLG[OFjrnti0} TTEF F'o LNR H cow 3-ur X# -II7 xO, u). 2Jd" 3.iTr'VIa9- 4, VAW,A68 " r xtrW(R2xPUP, 9) =?" L O-WW W, ID -2111W 4 -IJr SEI F ALJGN G i UBM R,. r LJR.2&R LAOwOZ62L, T x6" EM tek Fi7F; 9) DU3W, 9).62 " 4?3�r S'xaltrr" 9) =l,Jra F$ FICIMI O SURRIAM FLFFt_Ok GROOM Q ANGLE AT TifP FE: 48 012FW SM H Ak R" I6PYbdUaM MFor 6i�sY deft l lA� OPME 2-W41" 6 i1EM i ffi O 2-VF 6 i2B= -f3F� O Gwmw IPRRMM 4.14" LAIR VAK UCRVAN A6B QO152Wp 0 s 3MV DUE REV BY I CONSANTS LATE OW BY NCRMWAR 9112T63 N CMWLWM aLU29F IWWNG 4'IHL ear @1LAA3 KIF PERFS MAWO TAAW XNI3AWCE3Pr i FEFSW W *222L9tt AR W- ?W RkOLiRG MW— WA M®J_ SEC ti, TOO RFC, ZW FOL i GOT F6L. 07r"7 ResFPJC a iidl7A7 VAtV.FC fAFIIIHnLOQkIMCOFROEC arE laratlat►�Al ska� No portion of the below Ork should be performed w /out firs king time to ensure No Accidents, No harm to People, and No damage to the Environment Example of seated Brinker Platelet i � x I NOT OPERABLE: Producer NS22 (P~# 2022230) Confirmed Surface Casin~eak Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator@bp.com] ~f~il~ Sent: Monday, June 07, 2010 4:09 PM ~~~ I I To: AK, D&C Well Integrity Coordinator; AK, OPS Nstar OIM; AK, OPS Nstar O&M TL; AK, OPTS Nstar Ops Support TL; AK, OPS Nstar Lead Tech; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Sauve, Mark A; Atkinson, Tim (CDI); Rochin, William R (CDI); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Janowski, Carrie; Holt, Ryan P (ASRC); Wellman, Taylor T; Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Producer NS22 (PTD# 2022230) Confirmed Surface Casing Leak Follow Up Flag: Follow up Flag Status: Blue Attachments: Producer NS22 (PTD #2022230).pdf; Producer NS22 6-7-2010 TIO Plot.doc All, Northstar Producer NS22 (PTD #2022230) has failed an MIT-OA to 1200 psi with diesel returns exiting the conductor of the well indicating a surface casing leak. The well is current) sy but in and pressure has been bleed off the IA and OA. The well is reclassified as Not Operable and shall remain shut in. Plan forward: 1. Slickline to set a down hole plug 2. Fullbore MIT-T and CMIT TxIA to 4200 psi A well bore schematic and TIO plot are included for your reference. «Producer NS22 (PTD #2022230).pdf» «Producer NS22 6-7-2010 TIO Plot.doc» Please call us if there are questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ,~~s ~ ~„ h -t 1, 8/20/2010 Northstar NS-22 PTD 2022230 6/7/2010 TIO Pressures Plot Well: NS-22 ~.. 4,OOi_i 3,000 x,000 1,000 03?13?10 03?2'0?10 03?27?10 04?03?10 04?10?10 04?17?10 04?24110 0501?10 05?OS?10 05?15?10 05?22?10 05?29?10 06?05!10 ~- Tbg -~ IA -~ OA OOA OOOA - On • • TREE _ ABB-VGI5-118" 5KSI WELLHEAD ABB-VGI 13-5/8 MULTIBOWL 5KSI ACTUATOR = BAKERI KB. ELEV = BF. ELEV = 56.51' 40.2' (CB 15.90. KOP = ,m -~ ~, Max Angle = 32T ~ - ~ ~ _._.a 43° @ 11377 Datum MD = 12114' _ Datum ND = 10500' SS NS22 13-318" CSG, 68#, L-80 BTC, ID = 12.415" 3707' ~lilll'lllltTl ~®= 2.75" @ '~~2~J' 3-1/2" XN NIPPLE I TOP OF 7" LNR I ~ 9-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681 " ~ 9-518" X 7" BKR ZXP LNR TOP PKR w /FLEX LOCK HGR, ID = 6.20" 12211' --) 3-112" FIBER OPTIC TRANSDUCER 12236' ({12223' ELM D) ~ 3-112" HES X NIP, ID = 2.813" 12257' 7" X 3-1/2" BKR LNR TOP PKR, ID = 2.875" 12284' 3-1(2" HES X NIP, ID = 2.813" 12295' ~-~ 3-112" HES XN NIP, ID = 2.75" {12307' ELM TOP OF 4-1 /2" LNR 3-1i2" TBG, 9.2#/ft, 13CR VAM-ACE, 0.0087 bpf, 1D = 2.992" 7" LNR, 26#, L-80 HYDRIL 521, 0383 bpf, ID = 6.276" PEF2FORATION SUMMARY REF LOG: GRjCCL 01(24!03 ANGLE AT TOP PERF: 40 @ 12760' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) OpnlSgz DATE 2-114" 6 12760 - 12818 O 02/02(03 2-114" 6 12833 - 12853 O 07!09!07 PBTD 12860 elm 4-112" LNR, 12.6#, 13CR VAM-AC~ 1288T~ 0.0152 bpf, ID = 3.958" ***3-112" CHROME TBG & 4-112'" NOTE: MMS WELL 1142' ~--~ 3-1/2" TRM-4E SSSV, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 5032 5910 4583 5335 29 28 SMOR SMOR DMY DMY BK BK 0 0 02/03/03 01!31!03 12306' -'13-1i2" X 4-1/2" XO, ID = 2.992"' 12307` 7" X 5" BKR ZXP LTP, ID = ?" - -- 12311' 4-112" SELF ALIGNING WLEG, 1D = 3.85" 12329' 7" X 5" BKR LNR HGR, ID = ?" 12339' 5" X 4-1(2" XO, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01127!03 N33E FINAL COMPLETION 06/29108 WRRiPJC DRAWING CORRECTIONS 02/07/03 MJF ADD PERFS 01105110 TA/PJC XN ELMD DEPTH CORRECTION 11104/05 BJM NEW FORMAT 02/15/06 RAC/PAC SAFETY NOTE-MMS WELL 07/22107 RMWPJC ADPERFS (07/09!07} 11/27/07 WRR/JC WELLHD/LOCATION CORRECTIONS NORTHSTAR WELL: N522 PERMff No: 2022230 API No: 50-029-23128-00 SEC 11, T13N, R13E, 1260' FSL & 647' FEL BP Exploration {Alaska) ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~ ~.~~~ , ~~ ~ a ~~ ',? (~~~~ .. ~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission MAY ~? ~ '~~~~ 333 West 7th Avenue ~°' Anchora e, Alaska 99501 ~a>st~~if~~~. g Anchoraa~ Subject: Corrosion Inhibitor Treatments of Northstar b~,.,~ ~-o-`'' a s - ~~~~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar 4/20/2010 Well Name PTD # API # Initial top of cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NSOS 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231 110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 'Not measured due to rig proximity. LJ by BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. ~~ ~q 1 ~'~( ,a~.-~. a~~~~~ 1`~l~'~ ~ -l~d`n ~~i~ ao~ alb 19t3~ If you have anv questions. please contact Joe Lastufka at (9071564-4091 Date: O 1-04-2010 Transmittal Number: 93120 Deliver Contents Bottom SW Name Date Contractor Run To De th De th Descri tion MEMORY PRODUCTION NS34A 12-20-2009 SCH 1 16000 19082 PROFILE PSP CD-ROM -MEMORY NS34A 12-20-2009 SCH PRODUCTION PROFILE PSP MEMORY PRODUCTION NS22 12-16-2009 SCH 1 12208 12826 PROFILE PSP CD-ROM -MEMORY 2 12-16-2009 SCH PRODUCTION PROFILE PSP CD-ROM - LDWG EDIT OF RST LOG DATA IN TIF FORMAT, NS33A 11-10-2009 SCH 25482 15961.5 WITH FINAL PDS DISPLAYS MEMORY PPROF WITH DEFT NS20 12-15-2009 SCH 1 17452. 18489 AND GHOST CD-ROM -MEMORY PPROF NS20 12-15-2009 SCH WITH DEFT AND GHOST MEMORY PPROF WITH DEFT NS21 12-12-2009 SCH 1 20520 22184 AND GHOST CD-ROM -MEMORY PPROF NS21 12-12-2009 SCH WITH DEFT AND GHOST Please ign d Re one copy of this transmittal. Thank You, ,~, t;. ~ t ~ ~~~ ~ ~:~ ~,~~ Joe Lastufka ~~'~`~~~ r Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS ~D~"_U l ~ r9~~~ ~~ t! ~~~~~ ,,,i _. _ <r i ly David Fair Christine Mahnken ~/ Corazon Manaois Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 n, �'z � �� , � � � � R � SEAN PARNELL, GOVERNOR ALASKA OIL ANI) GALS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS22 Sundry Number: 309-424 AAN*X` -DEC 2 2 2009 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, rM o m 4issomm DATED this /Fday of December, 2009 Encl. STATE OF ALASKA / ' ALA *OIL AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS DEC 1 5 2009 20 AAC 25.280 1. Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate❑ - Re -od r fic�l G� COMMOSSion Alter casing ❑ Repair well ❑ Plug Perforations El Stimulate❑ Other Specify R�t1ehi!I'r1g8 Change approved program❑ Pull Tubing[] Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill ri I BP Exploration (Alaska), Inc. Development 0 - Exploratory ❑ 202-2230- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23128 -00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No NS22 - 9. Property Designation (Lease Number): 10. Field / Pool(s): OCSY -0181 NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12887 11141.75 12860 11121 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3663 13 -3/8" 68# L -80 44 3707 44 3413 4930 2270 Intermediate Production 10638 9 -5/8" 47# L -80 42 10680 42 9471 6870 4760 Liner 2012 7" 26# L -80 10457 12469 9292.55 10825 7240 5410 Liner 584 4 -1/2" 12.6# 13CR80 12303 12887 10699 11142 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Grade: Tubing MD (ft): SEE ATTACHED - 3 -1/2" 9.2# Tubing 13Cr80 40-12303 Packers and SSSV TVDe: 3 -1/2" TRM4E Packers and SSSV MD and TVD (ft): 1127 1113 9- 5/8 "X7 BKR ZXP LNR TOP PKR 10457 9293 7'X3 -1/2" BKR LNR TOP PKR 12257 10664 7'X5" BKR ZXP LTP 12303 10699 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2009 Oil ❑r - Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correcgl to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title Production Engineer Signature Phone Date 564 -4660 12/15/2009 Prepared by Gary Preble 5644944 ^` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / tJ . N D APPROVED BY 'O Approved by: COM IONER THE COMMISSION Date: !� e f 7 N A L '� Form 10403 Revised 07/2009 Submit in Duplicate NS22 202 -223 PERF ATTACH Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS22 2/2/03 PER 12,760. 12,818. 11,045.17 11,089.32 NS22 7/9/07 APF 12,833. 12,853. 11,100.71 11,115.91 n AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET . FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i • PERFORATING PROCEDURE Ver 4 0 06104/01 Rom r�utuwuMa�au Well: NS22 API #: 50-029- 23128 -00 .................................... ............................... ............... ............................... Date: 12/11/09 Prod Engr Mark Sauve Office Ph: 564 -4660 H2S Level: ... ............... ............................... ......................... ............................... ................................... ............................... Home Ph: 336 -6128 0 ppm Cell: 865 ............ ...... .......................... ............................... CC or AFC: NSFLDWL22 Detail Code: Description: Drift to TD with Dummy Gun, Perforate ....................................... ............................... WBL Entries IOR Type Work Description 200 S Drift to TD with Dummy Gun 200 1 E JPerforate from 12,740'- 12,853' MD Well Objectives and Logging Notes: For the a detailed NS22 well history, please see Pert program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by adding & re- perforating 113' of the oil column. Please note that the perforations will be dependent on the drift information. , Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Attachment: Reference Log Tie in Log Add 0 feet .............. Log: Jewelry /CCL JewelrY GR /CCL to the tie -in log to be on Date: 1/24/2003 1/24/2003 depth with the reference log. Company: Schlumber er Schlumber�er ......................... .......................... Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad/Reflperf 12,740' - 12,853' 12,740' - 12,853' 113' 6 60° 0 Ivishak Add &Re -Pert ............................. ................ .................... .......................... ................... ......................................................... ............................... ........................... -... ...................... ..... - ... . .............................. .............................. ................ .................... ....... I ............. I.... ................... ......................................................... ............................... 0 . ............................... . ............................... .............................. .............................. ................ ........I........... .......................... ................... 0 ........................................................ ............................... . ...........I ................... .. ............................... .............................. .............................. ................ ......... .......................... ................... ........................................................ ............................... Gas Jetting Expected? No At what Depth? N/A .............................. ................... Requested Gun Size: 2.25 Charge: 2306 PJ ....... .. ............................... Desired Penetration: 17.7 Entry Hole Diam: 0.3 Is Drawdown Necessary/Desired/Unnecessary During Perforating N A . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Describe below how to achieve drawdown (check w/ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .................................................... Tie in to Jewelry @ MD Tie in using: Schlumberger GR/CCL Jewelry Lod dated 1/24/03 Minimum ID: 2.75 in Min ID Type: 3.5" XN Nipple .......... @ 12,295 'MD ................... WLEG Depth: 12,306 ft MD Casing Size: 4.5 in 12.6# 13 -CR Liner Est Res. Pres. @ 12,906 MD 110' SS 5,092 psi ...................... ......... ............................ Last Tag: 12.816 ft SLMD on 5/3/2008 .............................. Well: NS22 Perforation Summary --------------- -- Date: API #: 50- 029 - 23128 -00 On -Site Prod Engr: ... ............................... ......................... ............................... ........................... ............................... PBTD ........................... ............................... General Comments: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ............................. . . . . ......................................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ......................... . ..................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ................... . ............................ . ........................................................... Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf O/ B / U .................................. ............................... ...................... ................ .................... ......................... O ......................................................... ............................... O /B /U - O O / B / U ................................. ............................... ..................... ................ ........ I ........... .......................... O ......................................................... ............................... O /B /U - O O /B /U ................................ ............................... ................................... ............................... .......................... 0 .................................................. ............. I....................... TREE = ABB -VGI 5 -1/8" 5KSI $ ACTUATOR AFEMPTES: ***3-1/2" CHROME TEIG & 4 -1/2" ACT BAKER LH D = ABB -VGI 13 518" MULTIBOWL 5KSI N S 2 2 CHRO LNR * ** NOTE: MMS WELL = KB. R EV = 56.51' BF. R EV = 40.2' (CB 15.9') 1142' 3 -1/2" TRM -4E SSSV, ID = 2.813" KOP = 321' Max Angle = 43° @ 11377' Datum MD = 12114' Datum TV D = 10500' SS 13 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" 3707' GAS LIFT MANDRELS STI MD I TV I DEV I TYPE I VLV I LATCH PORT DATE Minimum ID = 2.75" @ 12295' 1 1 5032 4563 29 1 SMOR DMY I BK 1 0 02/03/03 3-1/2" XN NIPPLE 2 5910 5335 28 SMOR DMY BK 0 01/31/03 TOP OF 7" LNR 10458' 10458' 9 -5/8" X 7" BKR ZXP LNR TOP PKR w / FLEX LOCK HGR, ID = 6.20" 9 -5/8" CSG, 47 #, L -80 BTM G ID = 8.681" 10680' 12211' 3 -1/2" FIBER OPTIC TRANSDUCER (12223' ELMD) 12236' 3 1/2" HES X NIP, ID = 2.813" 12257' 7" X 3-1/2" BKR LNR TOP PKR, ID — = 2.875" 12284' 3 -1/2" HES X NIP, ID = 2.813" 12295' 3-1/2" HES XN NIP, ID = 2.75" (12298' ELM D) TOP OF 4 -112" LNR 12303' 12306' 3 -1/2" TBG, 9.2 # /ft, 13CR VAM -ACE 1231_1_ E - 1 - 23 — OT - 1 — { 7" X 5" BKR ZXP LTP, ID 0.0087 bp ID = 2.992" ' p 12311 47/2" SELF ALIGNING WLEG, ID = 3.85" 7 LNR, 26 #, L -80 HYDRIL 521, 12469' 12329' 1 .0383 bpf, ID = 6.276" 12339' PERFORATION SUMMARY REF LOG: GR/CCL 01/24/03 ANGLE AT TOP PERF: 40 @ 12760' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -1/4" 6 12760 - 12818 0 02/02/03 2 -1/4" 6 12833 - 12853 O 07/09/07 F 12860 eim 4 -1/2" LNR, 12.6 #, 13CR VAM -ACF 12887' 0.0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 01/27/03 N33E FINAL COMPLETION 06/29/08 WRR/PJC DRAWING CORRECTIONS WELL: NS22 02/07/03 MJF ADD PERFS PERMrf No: F 2022230 11/04/05 BJM NEW FORMAT AN No: 50- 029 - 23128 -00 02/15/06 RAUPAG SAFETY NOTE- MMS WELL SEC 11, T13N, R13E, 1260' FSL & 647' FEL 07/22/07 RMH/PJC ADPERFS (07/09/07) 11/27/071 WRR1JC WELLHD /LOCATION CORRECTIONS BP Exploration (Alaska) • ~ ~ ~ ~ g ~ -~ ~~~ ~ ~p ~~~` ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~F ~ ~ ~ kE ~ ~ ~ `~N~ ~ ~ ~ ~ ~ C ~G~.~~.~ $ ~ ~ ~ ~ F~ ~{a~~`~ F F k ~`~ ~ ~ ?' ~a~`~ syy ~` ~ ~~ ~{, . ~; C n ~~~ ~~ r~- !p-~ S~ 6Q~°-~F } {~~ ~i: k-s~~~ ?~.v'~ E..~_~~ E~:~~ E~ .r~ 'F~~. ~ .,d._ ,~.i 6G F~. ~ ~ ~~~''~ ~i 1~.4 AI~SSA OII, A1~TD GA-5 COI~TSERQATIOI~T COMI~II5SIOI~T Mr. Jack Lau Well Engineer • ~ ~~1 SEAN PARNELL, GOVERNOR ~~~ jSr d ~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ,~ FAX (907) 276-7542 BP Ex loration Alaska Inc. ~> ~~~ti' P ( ), ,.,. ; i-< < . ~.~~.. _ P.O. Box 196612 ~ '` ° ° °. Anchorage, AK 99519-6612 ,, `~ d-"' Re: Northstar Field, Northstar Oil Pool, NS22 ~v ~~ ~ Sundry Number: 309-318 Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907j 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair .~ DATED thisZ ~ day of September 2009 Encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS , ~ ~ ~n anr. ~s ~an , ' R~ ~ ~:~e~~F~' _, ~/S ~ s ~~ ` . 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate^ Re-enter Suspended Well _; ^ Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate0 - Other Q Specify: , Bull Head Mud Acid Change approved program^ Pull Tubing~ Perforate New Pool ^ Time Extension ^ SIT 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Q_ Exploratory ~ 202-2230- 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23128-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing F~cception Required? Yes ^ No ^ NS22 0 9. Property Designation (Lease Number): 10. Field/Pool(s): OCSY-0181 - NORTHSTAR Field / NO RTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12887 _ 11141.75 12860 11121 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor Surface 3663 13-3/8" 68# L-80 44 3707 44 3413 4930 2270 Intermediate Production 10638 9-5/8" 47# L-80 42 10680 42 9471 6870 4760 Liner 2012 7" 26# L-80 10457 12469 9292.55 10825 7240 5410 Liner 584 4-1/2" 12.6# 13CR80 12303 12887 10699 11142 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.2# 13Cr80 40 -12303 Packers and SSSV Tvqe: 3-1/2" TRM-4E Packers and SSSV MD and ND (ft): 1127 1113 9-5/8"X7" BKR ZXP LNR 70P PKR 10457 9293 7"X3-1/2" BKR LNR TOP PKR 12257 10664 7"X5" BKR ZXP LTP 12303 10699 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ F~cploratory ^ Development Q- Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/19/2009 Oil Q_ Gas ^ WDSPL ~ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact ~ack Lau Printed Name ~ack Lau Title ~lyell Engineer Signat re Phone Date 564-5102 9/9/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Condi i ap al: Notify Commission so that a representative may witness Sundry Number: ~~,,//~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ~ Other: ) L S b t F R i d ~ ~ l ~ u sequen orm equ re : / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ ~/ ~RIGiNAL ~~._~ ~~~.~~w ~~~ . ~ ;. ,~~~ Form 10-403 Revised 07/2009 ~~- `~' /7 O~ ~~~i Submit in Duplicate NS22 202-223 PERF ATTACHMENT ~ ~J ~- Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS22 2/2/03 PER 12,760. 12,818. 11,045.17 11,089.32 NS22 7/9/07 APF 12,833. 12,853. 11,100.71 11,115.91 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE No portion of the below work shouid be performed w/out first taking time to ensure To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Welis Engineer Mark Sauve, Northstar PE Subject: NS22 Bullhead Mud Acid, SIT Treatment AFE: NSFLDWL22-C Date: September 8th, 2009 (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Cost: $200M IOR: 200 Please perform a bullhead mud acid treatment on NS22 per the below procedure. 1 D TIFL (Pre-Mud Acid Treatment) 2 F Bullhead Mud Acid and SIT w/ Diversion Current Status: Online Operable Producer Last Test: 06/14/09: 1,261 BOPD, 643 BWPD, & 32,861 MSCFD Max Inclination: 63° at 10,180'; ~34° at Perfs Max Dog Leg: 5.8 at 16,500'MD Minimum ID: 2.75" at the 3'h" XN Nip @ 12,295' MD Last TD tag: 05/03/08: Tagged TD at 12,816'SLM w/ 2.5" Cent, PDS SBHPS Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP/BHT: 05/03/08: 5,079 psia / 253°F @ 11,100 ft ss Obiective Based on the historical scale issues at Northstar, the declining benefit of HCI treatments, and the indication of skin, the below mud acid and scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. A multi stage diversion treatment will be performed in an attempt to open and treat all perforated intervals Well Historv NS22 is a North Star producer originally completed in 2003 with chrome 3'h" tubing and chrome 4~h" liner. Initial oil production was ~7000 bopd in 2003 and was scale inhibited with VX7377 to prevent calcium carbonate build up. An HCI/SIT treatment performed in Aug-05 resulted in a 400 bopd increase and confirmed the presence of calcium carbonate scale damage. Two successive HCI treatments in April-06 and Jan-07 resulted in 108 and 0 bopd increased, respectfully, indicating a declining benefit of using acid to treat the damage. Based on the declining historical rate benefits of treating NS22 with HCI and the presence of skin on PI curves, the below mud NS22 Bullhead Acid & SIT Treatment Paae 1 of 13 No portion of the below work should be performed w/out first taking time to ensure mage acid/scale inhibition treatment is proposed. This procedure is pending the results of the initial NS mud acid treatment on NS05, scheduled for Sept-09. Risk Discussion A risk review was held between the Wells Group and the North Star teams on 2/17/09 to discuss the risks associated with pumping aggressive HCL treatments and evaluate the feasibility of a HF treatment at Northstar. Risks were identified and mitigation plans have been developed. Additionally please review any lessons learned from the initial NS mud acid treatment on NS05 It is quite evident from the previous experience where using just HCI for stimulation, that main formation damage is calcium carbonate scale. This calcium carbonate poses an additional challenge for any sandstone acidizing treatment containing HF, as precipitation of Calcium Fluoride is irreversible once it happens and we must do whatever we can to avoid it. Using a regular 10 to 15%HCI treatment before the sandstone acidizing to remove most, if not all carbonate material, will greatly reduce the possibility of Calcium Fluoride precipitation. Historical Tbg/IA/OA data illustrates a large differential pressure between the tbg, IA, and OA which collaborates with all available data indicating the tubing has integrity and there is no risk of pushing acid into the IA. Acid returns will be neutralized during flow back by pumping MagOx slurry through the tree cap to mitigate the risk of flowing live acid through the facility and down the disposal well. This procedure proved successful during the March-09 NS16 and NS19 HCI jobs. It is critical to have twice the volume of MagOx necessary onsite to neutralize the treatment volume of acid. Action Items from 2/17/09 risk review. • Pump and other process components were verified to be resistant to acid. • Soft PSV components can be susceptible to HCl and HF. Risk is minimal as operations will mitigate high pressures by establishing an open flow path from the treated well to the disposal well • Using a test separator to bypass the facility was evaluated, however this option is not recommended due to additional risk added by rerouting flow and limited space on NS. • Low/settling points in system will be inspected before and after acid treatments. • CIC inspection of water injection header before and after acid treatments. • Portable acid shower/wash on site. An additional eye wash station is located in NS shop. . • Contingency patch/sleeve in case of water injection header failure - North Star Ops will evaluate the need for a contingency repair • Schlumberger will provide Slicker Suits and associated acid resistant PPE for Northstar Ops NS22 Bullhead Acid & SIT Treatment Page 2 of 13 No portion of the below work should be performed w/out ~rst taking time to ensure • A pre-task risk assessment will be performed before sampling returns at the test separator. Use appropriate PPE and acid resistant sample containers. North Star ops have taken on the role of sampling Flowback at the test separator. ~ SimOps with Drilling to ensure the treatments are scheduled to avoid rig interrupt~ons • Corrosion inhibitor package injected at wellhead during acid during Flowback ~vas deemed not necessary due to the neutralization of the acid at the wellhead. • HF Neutralization - Mag Oxide slurry Injection at Wellhead upon acid Flowback Please review the following sections of the PE manual. <htt~://alaska.b~web.b~.com/sst drillin~ wells ~emanual/> Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back Basic Proqram Phases • Tubing Pickle • Immediate Pickle Flowback • Cool/Condition Wellbore • 1St Stage HCI/Mud Acid Treatment • Wax Bead Diversion • 2"a Stage HCI/Mud Acid Treatment • Wax Bead Diversion • 3`d Stage HCI/Mud Acid Treatment • Immediate Flowback of Spent Acid w/ MagOx Neutralization • Sampling Program • Cool/Condition Wellbore • 1St Stage Scale Inhibition Treatment • Wax Bead Diversion • 2"a Stage Scale Inhibition Treatment • Wax Bead Diversion • 3rd Stage Scale Inhibition Treatment • Flowback • Sampling Program Wellwork Summarv A summary of well work activity is outlined below. NS22 Bullhead Acid & SIT Treatment Page 3 oi' l 3 No portion of the below work should be performed w/out ~irst taking time to ensure o cci en s, arm o eop e, an o amage e nv~ronmen Operational Highlights ** [~~~~~ P~i=;,•:~] [t'ie~u R~cent] (nvte: thrs data rs associated to the orrgrna! welJ and any subsequenf wellt~o Date C Oa/09I2007 20' Adperfs Closer to the OVUC --~ ~30 BOPD Increase E~~it C~elete O1f30l2a07 Bullhead Acid ~no L066~ --? No eenefit Edit ~eleta 04/0612006 Acid Only (no L066): --> 108 bbls oil inc. Edit Gelete 08l13J2005 Acid/SIT w. L066: --> 440 bbls oil inc. E~~it Delete 10f26f2004 Scale inhibitor treatment with 27,6 Bbls af VX7377 Edit C?elete 08f29~2Q03 SIT w, VX7377: No response Edit Dzlete 01/31/2003 Initial SlicklinelPerfs: 12,760' - 12,818' {58'~ Edlt ^P~ztP Ann Comm Historv: N/A Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 677-2599 (h) with any questions, comments, or concerns. Stimulatior~ Ta'r et ` Open Perforations NS22 Bullhead Acid & SIT Treatment Page 4 of 13 Zone MDT MDB H Status TZE/TZD 12,760 12,818 58 OPEN TZD/TZC3 12,833 12,853 20 OPEN Total Per forated Foota e 7 8' No portion of the below work should be performed w/out first taking time to ensure 0 Design Details Total Footage 78' # of Perforations ~468 Welibore Volume 114.1 bbl (to top perf at 12,760'MD) Acid Design Pickle - 100 gal/1000ft 10% HCI Pre-Flush - 100 gal/ft 6:1 Mud Acid - 100 al/ft Acid Volume Pickle - 30 bbls 10% HCI Pre-Flush - 185 bbls 6:1 Mud Acid - 185 bbls Diversion Design 6#/ft at 1.5 ppg in 30# HEC Gel Diversion Volume 10 bbls total Wax Beads in 30#HEC Gel Reservoir Pressure 5,079 psia / 253°F @ 11,100 ft ss GLV°s All GL Mandrels are Dummied Pre-Acid Stimulation : Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash 1. Obtain NS22 oil sample and deliver to Schlumberger Well Services lab for pre-job emulsion/sludge testing at least 5 days prior to acid stim. Verify mud acid design is acceptable for application. Test both live and spent acid with the crude oil, to ensure there is no sludge or emulsions. SurfactandMutual Solvent/Anti-sludge treatment should be designed based on lab testing whenever is possible. 2. Evaluate EC5526A and NS Oil compatibility test results. Contact Raul Diaz at rodiaz@nalco.com or Derek Lewis / Max Jensen at 659-8237. 3. Arrange DHD perform TIFL to ensure tubing has integrity. If the IA FL is deeper than 500' top off IA. If TIFL fails call Jack Lau at 564-5102 to discuss way forward. 4. Mobilize pumps, tanks, portable acid shower and acid transport to Northstar. Ensure Schlumberger provides Slicker Suits and associated HF acid resistant PPE for personnel on location and sampling returns during flow back. NS22 Bullhead Acid & SIT Treatment Page 5 o~f I 3 No portion of the below work should be performed w/out first taking time to ensure 5. Order out necessary NH4C1 and diesel to flush both the pickle and the acid treatment. See attached Volumes table. 6. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption and that the appropriate sized orifice plate is installed. Bullhead Mud Acid and Scale inhibition Treatment • Filter all fluids that will enter the perforations to 3 microns absolute. • Do Not exceed maximum pump pressure of 4000 psi when sweepinq qas out of the tubing and Do Not exceed 3500 psi when the wellbore is liquid packed. • NS20 is equipped with 3Yz" 13-CR tubing and 4~/z" 13-CR liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Send an electronic copy of the treatment report including digital, ASCtI or an EXCEL copy of pumping rates and pressures to Mark.Sauve C~ bp.com and Jack.Lau @ bp.com. 7. MIRU. 8. Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. • Ensure twice the volume of MagOx required to neutralize total volume of Mud Acid is onsite. • Ensure all onsite personnel are equipped with HF retardant slicker suits. 9. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. 10. Preheat filtered NH4C1 and diesel to 90°F. (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture NS22 Bullhead Acid & SIT Treatment Page 6 of I 3 No portion of the below work should be performed w/out first taking time to ensure 11. PT Dowell surface lines to 5000 psi. Tubing Pickte Treatment ' 12. Pickle the tubing by pumping the following acid design at 2 bpm. Do not exceed 3500 psi max pumping pressure. This is a practice that will help remove excess iron and debris from wellbore. Pump at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Note: Do not pump more than 113 tOtal bblS during pickle treatment. It is critical that the acid not reach perfs. Wellbore volume to top perf is 114.1 bbls. 12% Acid Mixture Design: 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer 0.5 % F078 Foaming Agent 13. Produce pickle back to test separator and well clean up tank. Total pickle volume to flowback is 188 Bbls, tubing + flowline + 10 bbls. Mud Acid Treatment 14. Reduce wellbore temperature and condition formation rock by pumping 320 bbls of filtered NH4CI + Surfactant F103 preheated to 85-90°F at 4-6bpm. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 190°F. Note: It is crucial that the water tem erature does not exceed the meltin tem erature of the Stage Fluid Type Vol, bbls Acid - Tubing Pickle (~100ga1/1000') 12% HCI 30 KCI or SW - Displacement Fluid 2% KCI or SW 33 Diesel cap Diesel 50 NS22 Bullheacl Acid & SIT Treatment Paoe 7 ofi 13 No portion of the below work should be performed w/out first taking time to ensure wax beads of 190°F. 100°F water should be used to reduce the wellbore temperature of 256°F to below the 190°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. This volume was calculated based on actual volurnes to cool NS-13 during the Aug-03 acid job. NH4CI will be the only aqueous solution to contact HF; this prevents precipitation of alkaline fluorides (Na, K). 15. Bullhead three stage acid treatment with wax bead diversion down the tubing per the treatment schedule below. Pump at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. It is critical to keep the pumping pressure high after diversion breakover is observed. Record pump rates, tubing, IA and OA pressures throughout the job. Final Displacement volumes (stages 16 + 17) are 14 bbls less than the volume to the top perf to ensure seawater does not contact the formation. Note: If the diversion locks up causing loss of injectivity, incrementally increase pump pressure to 3500 psi (max pump pressure while liquid packed) and hold for leak off. If no leak off occurs bleed surface pressure to 0 psi and incrementally incr.ease pressure to 3500 psi looking for leak off. Repeat pressure cycles as needed. If this does not work, as a final contingency flow back 1-2 bbls and continue with pump schedule. 253 min NS22 Fullbore Mud Acid Pump Schedule Stage Fluid Fluid Cum # Stage Fluid Vol Rate Time Fluid Descri tion T e bbl b m min bbls 1 Coolin 3% NH4CI no U67 320 6.0 53 320 2 Conditioning 3% NH4CI 30 6.0 5 350 3 Acid Pre-Flush 10% HCI 60 5.0 12 410 4 Acid 6:1 Mud Acid 60 5.0 12 470 5 OverFlush 3°Io NH4CI i 30 5.0 26 600 6 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 605 7 Spacer 3% NH4CI 5 5.0 1 610 8 Acid Pre-Flush 10% HCI 60 5.0 12 670 9 Acid 6:1 Mud Acid 60 5.0 12 730 10 OverFlush 3% NH4CI 130 5.0 26 860 11 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 865 12 Spacer 3% NH4CI 5 5.0 1 870 13 Acid Pre-Flush 10% HCI 65 5.0 13 935 14 Acid 6:1 Mud Acid 65 5.0 13 1000 15 OverFlush 3% NH4CI 155 5.0 31 1155 16 Displacement Seawater 50 3.0 17 1205 17 Dis lacement Diesel 50 3.0 17 1255 NS22 Bullhead Acid & SIT Treatment Page 8 of 13 No portion of the below work should be performed w/out first taking time to ensure Total Fluid Volumes 12°/a HCI Pickle 30 bbis 10% HCI 185 bbls 6:1 Mud Acid 185 bbis 3% NH4CI 775 bbls Wax Beads + 30#HEC 10 bbls 1155 Total Additives Volumes (Disclutlinq PlcKle Voiumes A261 Corrosion Inhibitor 0.6% 93 gal A153 Corrosion Inhibitor 8 124 Ibs A179 Corrosion Inhibitor 4 62 Ibs W54 NonEmulsifier 0.5% 78 gal W60 Anti-Sludge 0.5% 78 gal F103 Surfactant 0.2% 96 gal L58 Iron Stabilizer 20 311 Ibs U74 Dispersant 2% 117 gal ~ J285 Ammonium Chloride 3% 8141 Ibs U67 Mutual Solvent 5% 956 al 6:1 Mud Acid A261 Corrosion Inhibitor -__ 0.5% 39 gal A153 Corrosion Inhibitor 8 62 Ibs A179 Corrosion Inhibitor 4 31 Ibs W54 NonEmulsifier 0.5% 39 gal W60 Anti-Sludge 0.5% 39 gal F103 Surfactant 0.2°/a 16 gal L58 Iron Stabilizer 20 155 Ibs L041 Chelatin A ent 50 389 Ibs 10% HCI A261 Corrosion Inhibitor 0.5% 39 gal A153 Corrosion Inhibitor 8 62 Ibs A179 Corrosion Inhibitor 4 31 Ibs W54 NonEmulsifier 0.5% 39 gal W60 Anti-Sludge 0.5% 39 gal F103 Surfactant 0.2% 16 gal L041 Chelating Agent 50 389 Ibs L58 Iron Stabilizer 20 155 Ibs 3% NH4CI - Conditionin Over Flush/S acer F103 Surfactant 0.2% 38 gal J285 Ammonium Chloride 3% 4780 Ibs U67 Mutual Solvent 5°/a 956 al 3% NH4CI - Coolin F103 Surfactant 0.2% 27 gal J285 Ammonium Chloride 3% 3361 Ibs NS22 Bullhead Acid & SIT Treatment Page 9 of 13 No portion of the below work should be performed w/out first taking time to ensure Note: Acid strength to be verified and documented via titration before /eaving Sch/umberger. P/ease note the acid fitrations on the WSR and have resu/ts availab/e on location. 16. Prepare for immediate acid flowback. Acid Flowback / MagOx Neutralization 17. Line-up the well to flow into the test separator and well cleanup tank for flowback. 18. RU LRS to swab for Mag OX slurry injection. 19. Produce ~170 bbls (tubing + flowline volumes = 178 bbls). 20. Pump Mag Ox slurry loaded at 1 Ib per minute into acid Flowback for neutralization. In the past the solution was watered down to utilize LRS to do the pumping, this is an acceptable option. Ensure sufficient fluid volumes are available to neutralize during the entire Flowback period. Expected Flowback time is 579 minutes based on Flowback rate of 1.3 bpm. Mag Ox Slurry rate based on the following calculation: Mg0 Slurry Loading (Ib/gal): 1.00 Flowback Volume (bbls): 765 Expected Return Fluid pH: 1.00 Flowback Time (min at 1.3 bpm): 579 Return Fluid Flow Rate (bbls/min): 1.32 Minimum Volume of Mg0 required (gal or Ibs): 553 Mg0 Slurry Required (gal/min): 0.96 Note: Have twice the required volume of Mg0 on site See the attached excel calculation to adjust Mag Ox slurry rate based on pH of un- neutralized flow back samples taken at test separator. The frequency of these samples is at the discretion of the PE. Northstar Operations will be taking the samples because of their familiarity with the process equipment. Ensure pre-job risk assessment is completed and appropriate PPE is dawned before sampling. Take samples using acid resistant container and work with SLB to determine sam le H. 21.Once clean-up volume of 1433 bbls is produced (Treatment 1255 bbl + Flowline 64 bbls) divert back to the plant and get two 6-hour tests. ,, ~ ~..~s ~~ ~ ~~ - ,~~ .5. ~ ~` ~ ~ ~~ ,~~, ~. ~ ~ ~ ~z r~-~ • ~ ~~ ~.~` „~ ,. .~ ~ ~Scale Inhibition Treatment ' - ~ ~ ~ °~~ r , s` "~ ~ ~ ~ MM ~ `~ ~~ NS22 Bullhead Acid & SIT Treatment Paae 10 of 13 - No portion of the below work should be performed w/out first taking time to ensure iesel, bullhead tubing per the ~Ilbore gas with ~espond with a ;ay below 0.70 of the tubing. ;ads are in the ~ breakover is job. off. If to , as a Cum Fluid 1 PreFlush/Cooling Diesel 350 6.0 58 350 2 Scale Inhibitor 100% EC5526A ACCESS 16 6.0 3 366 3 OverFlush Diesel 42 5.0 8 408 4 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 413 5 Spacer Diesel 5 5.0 1 41 S 6 Scale Inhibitor 100% EC5526A ACCESS 16 5.0 3 434 7 OverFlush Diesel 42 5.0 8 476 8 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 481 9 Spacer Diesel 5 5.0 1 486 10 Scale Inhibitor 100% EC5526A ACCESS 16 5.0 3 502 11 OverFlush Diesel 56 5.0 11 558 12 Displacement Seawater 50 3.0 17 608 13 Dis lacement Diesel 50 3.0 17 658 133 min 23. Shut well in for 4 hours to allow scale inhibitor absorption. lowback NS22 Bullhead Acid & SIT Treatment Page 1 I of 13 No portion of the below work should be performed w/out first taking time to ensure Procedure Contacts: Mark Sauve WK: 564-4660 Cell: 748-2865 NS22 Bullhead Acid & SIT Treatment Jack Lau WK: 564-5102 Cell: 227-2760 Page 12 of 13 No portion of the below work should be performed w/out first taking time to ensure o cc~ en s, arm o eop e, an o amage e nv~ronmen • ~ ! r~= nee-vc~~-,ra~ ~ s~-~rrNOres: ~-~r~i c~g~rec3a ~-~n- ~~' 22 a~ao~ u~xr•• r~arE: rws w~u 11d2' 112"TFtl~MdE3SSV.D=2.813' ~ 13-3~8" CSQ 8&N.1-80 BTG D=12.415' 3 GAS L~'f t~{ANGRfi8 Minimum ID = 2.75" aQ 12295' 3 1l2" XN NIPPLE n~P OF r Wt 1045~8' 9-5r~' x r BicFt 7a~ t.NR m~ ~ w 1 FLEX LOCX HGR ~= 8.28" f-5f8" CSG, 4Tff 1-80 BTM~G D~&881' 12211' 3-1/2 fB~taP7'ICTRANSISLlCBt (tY1~3' B.MOj 12236' S-112' F~3 X t~ D~ 2.813• 1225T' r x&11r eKR u~ra>Fltit. o=2.a~5 12284 3-1~2't~Sxt~ D=2813' 12295' &112'l~6.57Q41~, D=2.75` (1YI98' $.N~ 1236B &1IE'X471TXO.D=2.88Q"' 'TCF~41lYlNR 123tF7' rxssxaz~w~~ o=r 3-tYL'TBG.~k!!(Gt3CRVAY-ACE 1 1' o.ooa~ n~e. o= 2.s~r 123t 1~ ~-~rr s~ nuct~carv~~c, lo = aa~~ r u~i 2eu. L-80 Mf Of~.521, 123Z9' r x s e~tLrsr -r~. n= r .Q383 bpf. D ~ 6.27~8' 12339` 5' X 41/2" J6D. D= 3,~i~' PBm elm 41 /2` lt*t. 12.8N,13CR Y/W -ACE, 0.01ffibpf.Dx3.958" NS22 Bullhead Acid & SIT Treatment Page 13 of 13 W~LFIEAD$ A~-VGl13-518'A~TBQWL ACT4l4TaR= BAKBt KB. 0.EV = 58.51' ~. ~ s +~.'Y ~~ '~5.~ KOP= 321' klax = 43' 11377' p~qy„pp = 12114' OiedmNO = 105t1U SS PHtFqiATiCN SiJWt~lRFttf t~F IOCa'~ Gfi~CCL 01t24l03 ANG1,EAtTOpPB~: 40~ 1278(Y r~ ra~~ w aoa~r~ os r« t~m~ ~ a~ S2E SPF IVT@tVAL (lub) apnlS4z OATE 2-4/4' 8 12`'1 -12818 O OZlOZib3 2-114" 8 12833-12853 O 07A0&J07 S MD Nd RE-/ TYPE VlV LATW PuRf L14TE 1 2 5032 5910 4563 5335 29 28 ~i~AOR SMOR OAAY CMN 8K 8K 0 0 6?/0:!!03 Otf31ltki • . U.S. Department of the Interior Submit original plus THREE copies,with ONE copy OMB Control No. 1010-0141 Minerals Management Service (MMS) marked "Public Information." OMB Approval Expires 11/30/2011 Application for Permit to Modify (APM) 1. WELL NAME (CURRENT) 2. SIDETRACK NO. 3. BYPASS NO. (CURRENT) 4. OPERATOR NAME and ADDRESS NS22 (~~F~(VT) U ~POO (Submitting office) loration Alaska Inc BP Ex 5. API WEIL NO. (12 digits) 6. START DATE (Proposed) 7. ESTIMATED DURATION (DAYS) p . 900 E. Benson Blvd. 50-029-23128-00-00 9/2009 2 Anchorage, Ak. 99508 8. 9. If revision, please ^ Revision list changes: WELL AT TOTAL DE PTH WELt AT SURFACE ' ~~b~~S Y 0181 ~ A~DL312799 - 11. AREA NAME 14. AREA NAME BEECHY POINT BEECHY POINT cK rvo. 7 CK NO. , 516 ~~~ Proposed or Completed Work 16. PROPOSED OR COMPLETED WORK (Describe in Section t7) PLEASE SELECT ONLY ONE PRIMARY TYPE IN BOLD AND AS MANY SECONDARY TYPES AS NECESSARY. ~ Enhance Production ^ Workover: ^ Completion: ~ Acidize ^ Change Tubing ~ Initial Completion ^ Artifical Lift ^ Casing Pressure Repair ^ Reperforation ^ Wash/Desand Well ~ Chartge Zone ^ Jet Well ^ Abandonme~t of Well Bore: ~ Modify Perforations 0 Utility 0 Permanent Abandonment ^ Initial Injection Well ~ Temporary Abandonment ^ Information: ^ Additional Fluids for Injection ^ Plugback to Sidetrack/Bypass ~ Surface Location Plat ~ Other Operations ~ Site Clearance ~ Change Well Name ^ Describe Operation(s) 17. BRIEFLY DESCRIBE PROPOSED OPERATIONS (Attach prognosis): Mill Scale, Acid Stimulation 18. LIST ALL ATTACHMENTS (Attach complete well prognosis and attachments required by 30 CFR 250.513(a) through (d),- 250.613(a) through (d); 250.1712(a) through (~; 250.1721(a) through (g); 250.1722(a) th~ough (d); or 250.1743(a). Descriptive Summary of Proposal, Wellbore Schematic 19. Rig Name or Primary Unit (e.g., Wireline Unit, Coil Tubing, Snubbing Unit, etc.) Surface Pump Truck 20. The greater of SITP or MASP (psi): 4500 21. Type of Safety Valve (SV): X SCSSV _SSCSV _ N/A 22. SV Depth BML (ft): ~ ~ z7 23. Rig BOP (Rams) 24. Rig BOP (Annular) Size: Working Pressure Test Pressure Working Pressure Test Pressure (inches) (psi) (psi) (psi) (psi) Low/High: Low/High: 25. Coiled Tubing BOP: 26. Snubbing Unit BOP: 27. Wireline Lubricator: Working Pressure BOP Test Pressure Working Pressure Test Pressure Working Pressure Test Pressure ~PS~) ~PS~) ~P51) (PS~) ~PS~) ~PS~) 300/4500 wp-5000 LowlHigh: Low/High: Low/High: 28. CONTACT NAME: 29. CONTACT TELEPHONE NO.: 30. CONTACT E-MAIL ADDRESS: Jack Lau 564-5102 Jack.Lau@bp.com 31. AUTHORIZING OFFICIAL (Type or print name) 32. TITLE Jack Lau Wells Engineer 33. AUTHOR N S A RE 34. DAT 1~ TN1S SPACE FOR MMS USE ONLY ._...... ...,..... ........ :... ... ............ . ... .. ... .. . . .. . .... . ; . . ....,. .......... , . ....,. . . .... . ... . . . . ......... . . ... ... ...... .. . . . ........ OVEQ BY: .. TITLE , .DATE MMS FOITII MMS-1 Y4 (November 2005 - Supersedes all previous versions of form MMS-124 which may not be used.) Page 1 of 2 • ~ Application for Permit to Modify (APM) Information Sheet 35) Question Information Questions Response Remarks a) Is HZS present in the well? If yes, then comment on the inclusion of a Contingency Plan for this operation. ^ YES p NO ^ N/A b) Is this proposed operation the only lease holding activity for the subject lease? If yes, then comment ^ YES 0 NO ~ N/A _ c) Will all wells in the well bay and Y related production equipment be shut-in when moving on to or off of an offshore platform, or from well to well on the platform? If not, please explain. ~ ES ~ NO p N/A d) If sands are to be commingled for this completion, has aproval been obtained? ^ YES ~ NO ~ N/A _ _ _ _ __ ; e) Will the completed interval be within 500 feet of a block line? If yes, then comment. ^ YES ~ NO 0 N/A ' _ _ f) For permanent abandonment, will casings be cut 15 feet below the mudline? If no, then comment. ^ YES ^ NO ~ N/A ~ - - PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT. The PRA (44 U.S.C. 3501 et. seq.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form, MMS-124, is estimated to average between 1-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance O~cer, Mail Stop 5438, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS Form MMS-124 (November 2008 - Supersedes all previous versions of form MMS-124 which may not be used.) Page 2 of 2 No portion of the betow work should be performed w/out first taking time to ensure • ~~ To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE Subject: NS22 Bullhead Mud Acid, SIT Treatment AFE: NSFLDWL22-C e Date: September 8th, 2009 (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Cost: $200M IOR: 200 Please perform a bullhead mud acid treatment on NS22 per the below procedure. 1 D TIFL (Pre-Mud Acid Treatment) 2 F Bullhead Mud Acid and SIT w/ Diversion Current Status: Online Operable Producer Last Test: 06/14/09: 1,261 BOPD, 643 BWPD, & 32,861 MSCFD Max Inclination: 63° at 10,180'; ~34° at Perfs Max Dog Leg: 5.8 at 16,500'MD Minimum ID: 2.75" at the 3~h" XN Nip @ 12,295' MD Last TD tag: 05/03/08: Tagged TD at 12,816'SLM w/ 2.5" Cent, PDS SBHPS Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP/BHT: 05/03/08: 5,079 psia / 253°F C~ 11,100 ft ss Obiective Based on the historical scale issues at Northstar, the declining benefit of HCI treatments, and the indication of skin, the below mud acid and scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. A multi stage diversion treatment will be performed in an attempt to open and treat all perforated intervals Well Historv NS22 is a North Star producer originally completed in 2003 with chrome 3'h" tubing and chrome 41/z" liner. Initial oil production was ~7000 bopd in 2003 and was scale inhibited with VX7377 to prevent calcium carbonate build up. An HCI/SIT treatment performed in Aug-05 resulted in a 400 bopd increase and confirmed the presence of calcium carbonate scale damage. Two successive HCI treatments in April-06 and Jan-07 resulted in 108 and 0 bopd increased, respectfully, indicating a declining benefit of using acid to treat the damage. Based on the declining historical rate benefits of treating NS22 with HCI and the presence of skin on PI curves, the below mud NS22 Bullhead Acid & SIT Treatment Paae 1 of 13 No portion of the below work should be performed w/out first taking time to ensure acid/scale inhibition treatment is proposed. This procedure is pending the results of the initial NS mud acid treatment on NS05, scheduled for Sept-09. Risk Discussion A risk review was held between the Wells Group and the North Star teams on 2/17/09 to discuss the risks associated with pumping aggressive HCL treatments and evaluate the feasibility of a HF treatment at Northstar. Risks were identified and mitigation plans have been developed. Additionally please review any lessons learned from the initial NS mud acid treatment on NS05 It is quite evident from the previous experience where using just HCI for stimulation, that main formation damage is calcium carbonate scale. This calcium carbonate poses an additional challenge for any sandstone acidizing treatment containing HF, as precipitation of Calcium Fluoride is irreversible once it happens and we must do whatever we can to avoid it. Using a regular 10 to 15%HCI treatment before the sandstone acidizing to remove most, if not all carbonate material, will greatly reduce the possibility of Calcium Fluoride precipitation. Historical Tbg/IA/OA data illustrates a large differential pressure between the tbg, IA, and OA which collaborates with all available data indicating the tubing has integrity and there is no risk of pushing acid into the IA. Acid returns will be neutralized during flow back by pumping MagOx slurry through the tree cap to mitigate the risk of flowing live acid through the facility and down the disposal well. This procedure proved successful during the March-09 NS16 and NS19 HCI jobs. It is critical to have twice the volume of MagOx necessary onsite to neutralize the treatment volume of acid. Action Items from 2/17/09 risk review. • Pump and other process components were verified to be resistant to acid. • Soft PSV components can be susceptible to HCl and HF. Risk is minimal as operations will mitigate high pressures by establishing an open flow path from the treated well to the disposal well • Using a test separator to bypass the facility was evaluated, however this option is not recommended due to additional risk added by rerouting tlow and limited space on NS. • Low/settling points in system will be inspected before and after acid treatments. • CIC inspection of water injection header before and after acid treatments. • Portable acid shower/wash on site. An additional eye wash station is located in NS shop. • Contingency patch/sleeve in case of water injection header failure - North Star Ops will evaluate the need for a contingency repair • Schlumberger will provide Slicker Suits and associated acid resistant PPE for Northstar Ops NS22 Bullhead Acid & SIT Treatment PaDe 2 of 13 No portion of the below work should be performed w/out first taking time to ensure • A pre-task risk assessment will be performed before sampling returns at the test separator. Use appropriate PPE and acid resistant sample containers. North Star ops have taken on the role of sampling Flowback at the test separator. • SimOps with Drilling to ensure the treatments are scheduled to avoid rig mterrupt~ons • Corrosion inhibitor package injected at wellhead during acid during Flowback was deemed not necessary due to the neutralization of the acid at the ~vellhead. • HF Neutralization - Mag Oxide slurry Injection at ~Iellhead upon acid Flowback Please review the following sections of the PE manual. <htm://alaska.bb~~eb.bti.com/sst drillin~ wells oemanual/> Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back Basic Proqram Phases • Tubing Pickle • Immediate Pickle Flowback • Cool/Condition Wellbore • 1 St Stage HCI/Mud Acid Treatment • Wax Bead Diversion • 2"d Stage HCI/Mud Acid Treatment • Wax Bead Diversion • 3rd Stage HCI/Mud Acid Treatment • Immediate Ftowback of Spent Acid w/ MagOx Neutralization • Sampling Program • Cool/Condition Wellbore • 1St Stage Scale Inhibition Treatment • Wax Bead Diversion • 2"a Stage Scale Inhibition Treatment • Wax Bead Diversion • 3rd Stage Scale Inhibition Treatment • Flowback • Sampling Program Wellwork Summarv A summary of well work activity is autlined below. NS22 Bullhead Acid & SIT Treatment Page 3 ot' 13 No portion of the below work should be performed w/out first taking time to ensure Operational Highlights ** [rs~~d t~te~,~4~] [E~ie~n~ RpcentJ (note: thfs data is assoclated ~o tr4e orrqrnat welt and any subsequent wellba D ate C 07/09I2007 20' Adperfs Closer to the OWC --? M30 BOPD Increase E~~I~ ~EI@tF O1/30/2007 Bullhead Acid (no L066) --~ No Benefit Edit Defete 04~06f2006 Acid Only {no L066): --~ 108 bbls ail inc. Edit Gelete 08f13/2005 Acid/SIT w. L066: --~- 400 bbls oi) inc, E~jit Delete 10f26/2004 Scale inhibitor treatment with 27.6 Bbls af V?{7377 Edit C~eleta 08f29l2003 SIT w, V}57377: Na response E+~it C~elet~ 01/31J2003 Initial SlicklinelPerfs: 12,?60' - 12,818' (58') E~~t L1PI'l'.~~.' Ann Comm Historv: N/A Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 677-2599 (h) with any questions, comments, or concerns. Open Perforations Zone MDT MDB H Status TZE/TZD 12,760 12,818 58 OPEN TZD/TZC3 12,833 12,853 20 OPEN Total Perf orated Footage 7 8' NS22 Bullhead Acid & SIT Treatment Page 4 of l 3 No portion of the below work should be perFormed w/out first taking time to ensure Design Details Total Footage 78' # of Perforations ~468 Weilbore Volume 114.1 bbl (to top perf at 12,760'MD) Acid Design Pickle - 100 gal/1000ft 10% HCI Pre-Flush - 100 gal/ft 6:1 Mud Acid - 100 al/ft Acid Volume Pickle - 30 bbls 10% HCI Pre-Flush - 185 bbls 6:1 Mud Acid - 185 bbls Diversion Design 6#/ft at 1.5 ppg in 30# HEC Gel Diversion Volume 10 bbls total Wax Beads in 30# EC Gel Reservoir Pressure 5,079 psia / 253°F @ 11,100 ft ss GLV's All GL Mandrels are Dummied Pre=Acid Stimulation ° I Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash 1. Obtain NS22 oil sample and deliver to Schlumberger Well Services lab for pre-job emulsion/sludge testing at least 5 days prior to acid stim. Verify mud acid design is acceptable for application. Test both live and spent acid with the crude oil, to ensure there is no sludge or emulsions. Surfactant/Mutual Solvent/Anti-sludge treatment should be designed based on lab testing whenever is possible. 2. Evaluate EC5526A and NS Oil compatibility test results. Contact Raul Diaz at rodiaz@nalco.com or Derek Lewis / Max Jensen at 659-8237. 3. Arrange DHD perform TIFL to ensure tubing has integrity. If the IA FL is deeper than 500' top off IA. If TIFL fails call Jack Lau at 564-5102 to discuss way forward. 4. Mobilize pumps, tanks, portable acid shower and acid transport to Northstar. • Ensure Schlumberger provides Slicker Suits and associated HF acid resistant PPE for personnel_on location and sampling returns during flow back. NS22 Bullhead Acid & SIT Treatment Pc1ae 5 Ot ~ ~ No portion of tMe below work should be performed wlout first taking time to ensure 0 5. Order out necessary NH4C1 and diesel to fiush both the pickle and the acid treatment. See attached Volumes table. 6. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption and that the appropriate sized orifice plate is installed. Bullhead Mud` Acid and Scale Inhibition Treatment . • Filter all fluids that will enter the perforations to 3 microns absolute. • Do Not exceed maximum pump pressure of 4000 psi when sweepinq qas out of the tubing and Do Not exceed 3500 psi when the wellbore is liquid packed. • NS20 is equipped with 3'/z" 13-CR tubing and 4~/2" 13-CR liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to Mark.Sauve@bp.com and Jack.Lau@bp.com. 7. MIRU. 8. Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. • Ensure twice the volume of MagOx required to neutralize total volurne of Mud Acid is onsite. • Ensure all onsite personnel are equipped with HF retardant slicker suits. 9. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. 10. Preheat filtered NH4C1 and diesel to 90°F. (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture NS22 Bullhead Acid & SIT Treatment Page 5 of 13 No portion of the below work should be performed w/out first taking time to ensure c 11. PT Dowell surface lines to 5000 psi. Tubing Pickle Treatment ~ 12. Pickle the tubing by pumping the following acid design at 2 bpm. Do not exceed 3500 psi max pumping pressure. This is a practice that will help remove excess iron and debris from wellbore. Pump at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Note: Do not pump more than 113 tOtal bblS during pickle treatment. It is critical that the acid not reach perfs. Wellbore volume to top perf is 114.1 bbls. Stage Fluid Type Vol, bbls Acid - Tubing Pickle (~100ga1/1000') 12% HCI 30 KCI or SW - Displacement Fluid 2% KCI or SW 33 Diesel cap Diesel 50 12% Acid Mixture Design: 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer 0.5 % F078 Foaming Agent 13. Produce pickle back to test separator and well clean up tank. Total pickle volume to flowback is 188 Bbls, tubing + flowline + 10 bbls. Mud Acid Treatment 14. Reduce wellbore temperature and condition formation rock by pumping 320 bbls of filtered NH4CI + Surfactant F103 preheated to 85-90°F at 4-6bpm. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 190°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the NS22 Bullhead Acid & SIT Treatment Page 7 of 13 No portion of the below work should be performed w/out first taking time to ensure wax beads of 190°F. 100°F water should be used to reduce the wellbore temperature of 256°F to beJow the 190°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. This volume was calculated based on actual volurnes to cool NS-13 during the Aug-03 acid job. NH4CI will be the only aqueous solution to contact HF; this prevents precipitation of alkaline fluorides (Na, K). 15. Bullhead three stage acid treatment with wax bead diversion down the tubing per the treatment schedule below. Pump at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. It is critical to keep the pumping pressure high after diversion breakover is observed. Record pump rates, tubing,lA and OA pressures throughout the job. Final Displacement volumes (stages 16 + 17) are 14 bbls less than the volume to the top perf to ensure seawater does not contact the formation. Note: If the diversion locks up causing loss of injectivity, incrementally increase pump pressure to 3500 psi (max pump pressure while liquid packed) and hold for leak off. If no leak off occurs bleed surface pressure to 0 psi and incrementally incr.ease pressure to 3500 psi looking for leak off. Repeat pressure cycles as needed. If this does not work, as a final contingency flow back 1-2 bbls and continue with pump schedule. NS22 Fullbore Mud Acid Pump Schedule Stage Fluid Fluid Cum # Stage Fluid Vol Rate Time Fluid Descri tion T e bbl b m min bbls 1 Coolin 3°/a NH4CI no U67 320 6.0 53 320 2 Conditioning 3% NH4CI 30 6.0 5 350 3 Acid Pre-Flush 10% HCI 60 5.0 12 410 4 Acid 6:1 Mud Acid 60 5.0 12 470 5 OverFlush 3% NH4CI 130 5.0 26 600 6 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 605 7 Spacer 3% NH4CI 5 5.0 1 610 8 Acid Pre-Flush 10°/a HCI 60 5.0 12 670 9 Acid 6:1 Mud Acid 60 5.0 12 730 10 OverFlush 3°/a NH4CI 130 5.0 26 860 11 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 865 12 Spacer 3% NH4CI 5 5.0 1 870 13 Acid Pre-Flush 10% HCI 65 5.0 13 935 14 Acid 6:1 Mud Acid 65 5.0 13 1000 15 OverFlush 3% NH4CI 155 5.0 31 1155 16 Displacement Seawater 50 3.0 17 1205 17 Dis lacement Diesel 50 3.0 17 1255 253 min NS22 Bullhead Acid & SIT Treatment Page 8 of 13 No portion of the below work shouid be performed w/out first taking time to ensure Total Fluid Volumes 12% HCI Pickle 30 bbls 10% HCI 185 bbls 6:1 Mud Acid 185 bbls 3% NH4CI 775 bbls Wax Beads + 30#HEC 10 bbis 1155 Total Additives Volumes (Discludinq Pickie Volumes A261 Corrosion Inhibitor 0.6% 93 gal A153 Corrosion Inhibitor 8 124 Ibs A179 Corrosion Inhibitor 4 62 Ibs W54 NonEmulsifier 0.5% 78 gal W60 Anti-Sludge 0.5% 78 gal F103 Surfactant 0.2% 96 gal L58 Iron Stabilizer 20 311 Ibs U74 Dispersant 2% 117 gal J285 Ammonium Chloride 3% 8141 Ibs ~ U67 Mutual Solvent 5% 956 al 6:1 Mud Acid A261 Corrosion Inhibitor 0.5% 39 gal A153 Corrosion Inhibitor 8 62 Ibs A179 Corrosion Inhibitor 4 31 Ibs W54 NonEmulsifier 0.5% 39 gal W60 Anti-Sludge 0.5% 39 gal F103 Surfactant 0.2% 16 gal L58 Iron Stabilizer 20 155 Ibs L041 Chelatin A ent 50 389 Ibs 10% HCI A261 Corrosion Inhibitor 0.5% 39 gal A153 Corrosion Inhibitor 8 62 Ibs A179 Corrosion Inhibitor 4 31 Ibs W54 NonEmulsifier 0.5% 39 gal W60 Anti-Sludge 0.5% 39 gal F103 Surfactant 0.2% 16 gal L041 Chelating Agent 50 389 Ibs L58 Iron Stabilizer 20 155 Ibs 3% NH4CI - Conditionin /Over Flush/S acer F103 Surfactant 0.2% 38 gal J285 Ammonium Chloride 3% 4780 Ibs U67 Mutual Solvent 5% 956 al 3% NH4CI - Coolin F103 Surfactant 0.2% 27 gal J285 Ammonium Chloride 3% 3361 Ibs NS22 Bullhead Acid & SIT Treatment Page 9 of 13 No portion of the below work should be performed w/out first taking time to ensure Note: Acid strength to be verified and documented via titration before /eaving Schlumberger. P/ease note the acid titrations on the WSR and have resu/ts availab/e on location. 16. Prepare for immediate acid flowback. Acid Flowback / MagOx Neutralization 17. Line-up the well to flow into the test separator and well cleanup tank for flowback. 18. RU LRS to swab for Mag OX slurry injection. 19. Produce ~170 bbls (tubing + flowline volumes = 178 bbls). 20. Pump Mag Ox slurry loaded at 1 Ib per minute into acid Flowback for neutralization. In the past the solution was watered down to utilize LRS to do the pumping, this is an acceptable option. Ensure sufficient fluid volumes are available to neutralize during the entire Flowback period. Expected Flowback time is 579 minutes based on Flowback rate of 1.3 bpm. Mag Ox Slurry rate based on the following calculation: Mg0 Slurry Loading (Ib/gal): 1.00 Flowback Volume (bbls): 765 Expected Return Fluid pH: 1.00 Flowback Time (min at 1.3 bpm): 579 Return Fluid Flow Rate (bbls/min): 1.32 Minimum Volume of Mg0 required (gal or Ibs): 553 Mg0 Slurry Required (gaUmin): 0.96 Note: Have twice the required volume of Mg0 on site See the attached excel calculation to adjust Mag Ox slurry rate based on pH of un- neutralized flow back samples taken at test separator. The frequency of these samples is at the discretion of the PE. Northstar Operations will be taking the samples because of their familiarity with the process equipment. Ensure pre-job risk assessment is completed and appropriate PPE is dawned before sampling. Take samples using acid resistant container and work with SLB to determine sam le H. 21.Once clean-up volume of 1433 bbls is produced (Treatment 1255 bbl + Flowline 64 bbls) divert back to the plant and get two 6-hour tests. Scale Inhibition Trea#ment `'~ ~~f ~~Ly ~~~ A NS22 Bullhead Acid & SIT Treatment Page 10 of 13 No portion of the below work should be performed w/out first taking time to ensure 22. After knocking down SIW HP with 1-2 tubing volumes (200-400 barrels) of diesel, bullhead three stage scale inhibition treatment with wax bead diversion down the tubing per the treatment schedule below. Pump at 3-5 bpm if possible when displacing wellbore gas with preflush. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi when liquid packed (to stay below 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. It is critical to keep the pumping pressure high after diversion breakover is observed. Record pump rates, tubing, IA and OA pressures throughout the job. Note: If the di~ersion locks up causing loss of injectivity, incrementally increase pump pressure to 3500 psi (max pump pressure while liquid packed) and hold for leak off. If no leak off occurs bleed surface pressure to 0 psi and incrementally increase pressure to 3500 psi looking for leak off. Repeat pressure cycles as needed. If this does not work, as a final contingency flow back 1-2 bbls and continue with pump schedule. NS22 Fullbore Scale Inhibitor Schedule Stage Fluid Fluid Cum # Stage Fluid Vol Rate Time Fluid Descri tion T e bbl b m min bbls 1 PreFlush/Cooling Diesel 350 6.0 58 350 2 Scale Inhibitor 100% EC5526A ACCESS 16 6.0 3 366 3 OverFlush Diesel 42 5.0 8 408 4 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 413 5 Spacer Diesel 5 5.0 1 418 6 Scale Inhibitor 100% EC5526A ACCESS 16 5.0 3 434 7 OverFlush Diesel 42 5.0 8 476 8 Diversion 1.5 PPA Wax Beads + 30#HEC 5 5.0 1 481 9 Spacer Diesel 5 5.0 1 486 10 Scale Inhibitor 100% EC5526A ACCESS 16 5.0 3 502 11 OverFlush Diesel 56 5.0 11 558 12 Displacement Seawater 50 3.0 17 608 13 Dis lacement Diesel 50 3.0 17 658 133 min 23. Shut well in for 4 hours to allow scale inhibitor absorption. owback NS22 Bullhead Acid & SIT Treatment Paae 1 1 of 13 No portion of the below work should be performed w/out first taking time to ensure r Procedure Contacts: Mark Sauve WK: 564-4660 Cell: 748-2865 NS22 Bullhead Acid & SIT Treatment Jack Lau WK: 564-5102 Cell: 227-2760 Paae 12 of 13 No portion of the below work should be performed w/out frst taking time to ensure ~ ~ NS22 Bullhead Acid & SIT Treatment Page 13 of 13 ~= aes-vc~~-~ra~ s+csi s~r7rwor~: ~-~ n• t~ac~e~re~ a~-t t2- ~ i Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 1:51 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-318 Approve Sent from my iPhone On Sep 18, 2009, at 10:29 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091808570.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808570.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808570.pdf> BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 • ~a~ z~~ May 26, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue /~(~/~ ~" 1.~ r ~ Anchorage, Alaska 99501 ~~ ~~ 4 ~~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~?,~~5 Andrea Hughes BPXA, Well Integrity Coordinator ~,{, BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~" '~~\ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0,5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS141~ 2052020 0.9 na 0.9 na 2.8 5/1/2009 NSi6 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5!2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 na na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3!2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 na * na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5!3/2009 *Not measured due to rig proximity. ~. ~ ~` L ~Uw ®~ 2009 • by '~~ Date OS-08-2008 Transmittal Number:92965 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (9071564-4091 a Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS05 05-04-2008 PDS 1 13096 13988 CORRELATION LOG STATIC TEMPERATURE / NS05 05-04-2008 PDS PRESSURE SURVEY CD-ROM CORRELATION LOG STATIC TEMPERATURE NS05 05-04-2008 PDS /PRESSURE SURVEY NS22 05-03-2008 PDS 1 12138 12852 CORRELATION LOG STATIC TEMPERATURE / NS22 05-03-2008 PDS PRESSURE SURVEY CD-ROM CORRELATION LOG STATIC TEMPERATURE NS22 0 03-2008 PDS /PRESSURE SURVEY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ~~~I~ MAY ~ ~ 2008 BPXA AOGCC Murphy Exploration DNR MMS ~~ N5.2.~' David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2- I 900 E. Benson Blvd. PO Box 196612 AnchoraDe, AK 995 1 9-66 1 2 B.P. Exploration (A/askaJ. lna SitatiC T@/n~L7e/'c'~1tU/'e~ P/'BSSU/'@ SU/'VBJ/ NS-22 North Star North Slope Surface -Before RlH Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 36.8 3642.14 0.5 36.6 3658.66 1.0 36.2 3672.42 1.5 36.2 3683.30 2.0 35.8 3691.46 2.5 35.5 3697.17 3.0 35.2 3700.84 3.5 35.0 3702.99 4.0 34.8 3704.34 4.5 34.7 3705.52 5.0 34.4 3706.99 5.5 34.2 3706.93 6.0 34.1 3706.88 6.5 33.8 3706.83 7.0 33.7 3706.79 7.5 33.5 3706.76 8.0 33.2 3706.72 8.5 33.1 3706.68 9.0 32.9 3706.65 9.5 32.8 3706.61 10.0 32.6 3706.59 AVERAGE 34.5 3696.82 Current Wellhead Read ings Wellhead Pressure (prig) : 3,700 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure si ) : N/A 7 8 9 10 Date: May 3, 2008 Temperature Data 40 35 LL ~' ~ 0 25 20 Ob~EM WE(( s'~F QQ. c,9 s f- PAOACTIYE ~I~QNOfTIC $ERVICfS Start time: 10:49:00 0 3800 3775 3750 3725 Q y 3700 a 3675 3650 3625 3soo 1 2 3 4 5 6 Minutes 7 8 9 10 Pressure Data 0 1 2 3 4 5 6 Minutes Pagel ~ O ~ ~ ~~^ 1 , c~ ~' 1S'd+ Cl B.P. Exploration (A/askaJ. lnc. Stai*iC TE/17PE/'c~tU/'B~ P/'BSSU/'B SU/'VE.'J/ NS-22 North Star North Slope 97,059' TI/Dss M.D. = 92,852' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 253.7 5,080.03 1.0 253.8 5,080.08 2.0 253.8 5,080.29 3.0 253.7 5,080.60 4.0 253.7 5,080.95 5.0 253.7 5,081.32 6.0 253.7 5,081.69 7.0 253.7 5,082.04 8.0 253.7 5,082.36 9.0 253.7 5,082.66 10.0 253.7 5,082.93 11.0 253.7 5,083.18 12.0 253.8 5,083.40 13.0 253.8 5,083.59 14.0 253.8 5,083.78 15.0 253.8 5,083.95 16.0 253.8 5,084.11 17.0 253.8 5,084.25 18.0 254.2 5,084.39 19.0 253.9 5,084.51 20.0 254.1 5,084.63 21.0 253.8 5,084.74 22.0 253.3 5,084.85 23.0 253.8 5,084.94 24.0 253.5 5,085.04 25.0 253.7 5,085.12 26.0 253.9 5,085.21 27.0 254.2 5,085.28 28.0 253.4 5,085.35 29.0 253.7 5,085.42 30.0 253.9 5,085.48 AVERAGE 253.8 5,083.42 Date: May 3, 2008 Temperature Data ~~ 253 LL 251 ~' ~ 249 247 245 Ob`EM WE[[SA~ 4p c~v s ~. w PROACTIVE DIOGNO]i1G SERVICES Start time: 12:13:00 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes Soso 5080 a v~ 5070 a 5060 5050 I I ~ I-~-I I I I I +~ 1 I I I i I r--i h-TI ! + I ~ I I i ~ 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes Page 2 Pressure Data B.P, Exploration jA/askaJ. lnc. Stat~C T@/7~PE/'c~tU/'@~ P/'BSSU/'@ SU/'VL'J/ NS-22 North Star North Slope ~ 9,029' TVDss M.D. = 92,873' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 253.4 5,078.83 0.5 254.2 5,078.86 1.0 253.6 5,078.89 1.5 253.3 5,078.92 2.0 253.0 5,078.95 2.5 253.5 5,078.98 3.0 253.3 5,079.02 3.5 253.2 5,079.05 4.0 253.2 5,079.08 4.5 253.2 5,079.11 5.0 253.2 5,079.14 5.5 253.2 5,079.16 6.0 253.2 5,079.19 6.5 253.3 5,079.21 7.0 253.3 5,079.24 7.5 253.3 5,079.26 8.0 253.2 5,079.28 8.5 253.2 5,079.30 9.0 253.2 5,079.32 9.5 253.2 5,079.33 10.0 253.2 5,079.35 10.5 253.2 5,079.37 11.0 253.2 5,079.38 11.5 253.2 5,079.40 12.0 253.2 5,079.41 12.5 253.2 5,079.42 13.0 253.2 5,079.44 13.5 253.2 5,079.44 14.0 253.2 5,079.46 14.5 253.2 5,079.47 15.0 253.2 5,079.48 AVERAGE 253.3 5.079.22 Date: May 3, 2008 Temperature Data Ob~EM WE[[ sA6 C~ c'v s ~ N PROACTIVE Di~ynosric SERVicn Start time: 12:50:00 255 253 ......................... .................. ................... ................................ .............. .............................................. a 251 ........................................................................................... ~' ~ 249 .................. ~ .....-...........................................--.................................................... - .........-...-. 247 ........................................................................................................................ ~ .....................-.. .........-...................-................................... 245 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5090 Pressure Data 5080 a a 5070 Soso 5050 -I t i~ i i~ i F ~ +---I ~ t{{ i F--F--~ i-f F} i~ i+-T 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 3 ~ ~ s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ B.P. Exploration (A/askaJ. lnc. NS-22 North Star North S/ope 90,979' TVDss M.D. = 92,747' Static Temperature/ Pressure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 252.1 5, 073.84 0.5 252.0 5,073.86 1.0 252.1 5,073.88 1.5 252.1 5, 073.90 2.0 252.0 5,073.91 2.5 252.0 5,073.93 3.0 252.0 5,073.93 3.5 252.0 5,073.94 4.0 252.0 5,073.95 4.5 252.0 5,073.95 5.0 252.0 5,073.95 5.5 252.0 5,073.96 6.0 252.0 5,073.96 6.5 252.0 5,073.96 7.0 251.9 5,073.96 7.5 251.9 5,073.96 8.0 251.9 5,073.96 8.5 251.9 5,073.96 9.0 251.9 5,073.96 9.5 251.9 5,073.96 10.0 251.9 5,073.96 10.5 251.9 5,073.96 11.0 251.9 5,073.96 11.5 251.9 5,073.96 12.0 251.9 5,073.96 12.5 251.9 5,073.96 13.0 251.9 5,073.96 13.5 251.9 5,073.96 14.0 251.9 5,073.96 14.5 251.9 5,073,96 15.0 251.9 5,073.96 AVERAGE 251.97 5,073.94 Date: May 3, 2008 Temperature Data 255 253 ti 251 ~' ~ 249 247 245 ob`EM WE[[ SAF 4~ c~v ~- v, PROACTIVE Di~ynosric SERVIC[f Start time: 13:08:00 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5090 5080 .................................................. .................................................................................................................................................................................. vii 5070 ....................................................... a 5oso ...................................................................................................................................................... ~ ........................................................................... 5050 0 1 2 3 4 5 8 7 8 9 10 11 12 13 14 15 Minutes Page 4 B.P. Exploration (Alaska). lnc. stet/C TB/r1pE/'c'~1tU/'E~ P!'BSSU!'B $[//'VEJ/ NS-22 North Star North Slope 90,879' Tl/Dss M.D. = 92,695' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.3 5,062.85 0.5 250.3 5,062.91 1.0 250.2 5,062.96 1.5 250.2 5,063.00 2.0 250.2 5,063.03 2.5 250.2 5,063.05 3.0 250.2 5,063.06 3.5 250.2 5,063.07 4.0 250.2 5,063.07 4.5 250.2 5,063.07 5.0 250.2 5,063.06 5.5 250.1 5, 063.06 6.0 250.1 5,063.05 6.5 250.1 5,063.05 7.0 250.1 5,063.04 7.5 250.1 5, 063.03 8.0 250.1 5,063.02 8.5 250.1 5, 063.01 9.0 250.1 5,063.00 9.5 250.1 5,062.99 10.0 250.1 5,062.98 10.5 250.1 5,062.97 11.0 250.1 5,062.97 11.5 250.1 5, 062.96 12.0 250.1 5,062.95 12.5 250.1 5,062.94 13.0 250.1 5,062.94 13.5 250.1 5,062.93 14.0 250.1 5, 062.92 14.5 250.1 5,062.91 15.0 250.1 5,062.91 AVERAGE 250.2 5,062.99 Date: May 3, 2008 Temperature Data LJA 253 a 251 ~' ~ 249 247 245 Ob`EM WE((SAE ~ c, Q 9~ W PaoAcrive Disynmric SFwvices Start time: 13:29:00 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5090 5080 N 5070 a 5060 5050 Pressure Data 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 5 a.P ~plo~at/o~ ~Algska~ 1~~. Static Temperature/ Pressure Survey NS-22 North Star North Slope 70,979' TYDss M.D. = 92,747' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 251.7 5,073.99 0.5 251.7 5,073.93 1.0 251.7 5,073.88 1.5 251.7 5,073.84 2.0 251.7 5,073.80 2.5 251.7 5,073.77 3.0 251.7 5,073.75 3.5 251.9 5,073.73 4.0 252.0 5,073.72 4.5 251.8 5,073.71 5.0 251.8 5,073.71 5.5 251.9 5,073.71 6.0 252.0 5,073.71 6.5 252.1 5,073.71 7.0 252.1 5,073.72 7.5 252.1 5,073.72 8.0 251.8 5,073.73 8.5 251.8 5,073.73 9.0 251.8 5,073.74 9.5 251.8 5,073.75 10.0 251.8 5,073.75 10.5 251.8 5,073.76 11.0 251.8 5,073.77 11.5 251.8 5,073.77 12.0 251.8 5,073.78 12.5 251.8 5,073.78 13.0 251.8 5,073.79 13.5 251.8 5,073.79 14.0 252.0 5,073.80 14.5 251.8 5,073.80 15.0 252.4 5,073.81 AVERAGE 251.9 5,073.77 Date: May 3, 2008 ~~~ 253 a 251 ~' ~ 249 247 245 Temperature Data ob~E~1- WE(( SpF QQ. c' s F~ M PROACTIVE Di~ynosric SEevicEf Start time: 13:51:00 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes solo Soso Page 6 Pressure Data B.P. Exploration (A/askaJ. lnc. Static Temperature/ Pressure Survey NS-22 North Star North Slope Surface -After P~t7H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 34.2 3,705.97 0.5 33.0 3,706.38 1.0 33.0 3,706.74 1.5 32.7 3,707.04 2.0 32.2 3,707.32 2.5 31.8 3, 707.57 3.0 31.7 3,707.80 3.5 31.7 3,708.02 4.0 31.3 3,708.21 4.5 30.9 3,708.38 5.0 30.9 3,708.53 5.5 30.8 3,708.65 6.0 30.5 3,708.76 6.5 30.5 3,708.84 7.0 30.5 3,708.91 7.5 30.2 3,708.96 8.0 30.2 3,708.99 8.5 30.1 3,709.02 9.0 30.0 3,706.96 9.5 29.9 3,707.80 10.0 29.9 3,707.67 AVERAGE 31.2 3,707.93 Current Wellhead Read in s Wellhead Pressure (psig) : 3,700 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure si ) : N/A Date: May 3, 2008 ao 35 LL ~+ 30 D 25 20 Temperature Data ob~EM WE(( SAF Q~ c'v W C' Z F~ N PROAC7iVE Di~ynosric SERViCEf Start time: 15:49:00 0 1 2 3 4 5 6 7 8 9 10 Minutes 3800 3775 ........................ 3750 ........................ 3725 ........................ Q in 3700 ........................ a 3675 ........................ 3650 ........................ 3625 ........................ 3600 Pressure Data 0 1 2 3 4 5 6 7 8 9 10 Minutes Page 7 w ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ e.P ~plo~at/on ~Alaska~ 1~~. Static Temperature/ Pressure Survey /Va~7'22 QpOb`EM WE~[.TAFC'7 North Stsr W North Slope ~ DoW/7ho% Temp/ Peas PROACTIVE DI~yROSTic SFRVICEI Date: May 3, 2008 Start time: 10:49:00 End time: 16:05:00 255 253 IL 251 ~ 249 247 245 Temperature Data -200 0 200 400 600 800 1000 1200 1400 1600 Minutes Page 8 • • e e bp Date 08-14-2007 Transmittal Number:92897 ~ '"' ZOO? OJmm¡SSiCn BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. t;)¢O ú 9 Log Top SW Name Date Contractor Run Depth Bottom Depth Loq Type <..>:tc... -11fa NS10 07-21-2007 SCH 1 4800 7975 WATERFLOW INJECTION :t~ O'3-'''~ NS32 07 -20-2007 SCH 1 3760 8075 WATERFLOW INJECTION 9 - dO-"" NS19 07 -08-2007 SCH 1 13650 13955 PERFORATION RECORD ~ - 03(... NS11 07 -06-2007 SCH 1 14450 14625 PERFORATION RECORD '11-()W NS13 07 -14-2007 SCH 1 11 534 11790 MEMORY PPROF - (~ NS24 07 -1 5-2007 SCH 1 11774 12476 STATIC BOTTOM HOLE ~-9J3 NS22 07 -09-2007 SCH 1 12600 12850 PERFORATION RECORD -08\ NS08 12-23-2005 PDS 1 9006 11406 CORRELATION LOG O,;) -ç)1t) NS21 07 -02-2005 PDS 1 21590 22249 DEPTH DETERMINATION 1:~ -/~d NS10 01-01-2006 PDS 1 4497 5497 CORRELATION LOG ~o fö h. ~ J.Ó )od. ;) (,) ~(JO c. JL--- Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer 5ti~NED AUG 1 7 2007 Petrotechnical Data Center Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA I ALÀYA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 4/11$/r D Stimulate D Other D D Waiver D Time Extension D o Re-enter Suspended Well D 5. Permit to Drill Number: ~ ?-/?~? R~C~/'vE2D JU¿ 1 ·7 " Ga,l: Co 4r¡c/¡or. flS. CO/1J. age ~Ssio. 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development w Stratigraphic Exploratory Service 202-2230 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 6. API Number: 50-029-23128-00-00/ 9. Well Name and Number: 56.51 KB / NS22 __ OCSY-0181 _ 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured 12887 / feet Plugs (measured) None true vertical 11141.75 feet Junk (measured) None Effective Depth measured 12882 ' feet true vertical 11137.95 feet Casing Length Size MD TVD Burst Collapse SURFACE 3663 13-3/8" 68# L-80 44 - 3707 44 - 3412.71 4930 2270 INTERMEDIATE 10638 9-5/8" 47# L-80 42 - 10680 42 - 9471.3 6870 4760 LINER 2012 7" 26# L-80 10457 12469 9292.55 - 10825.09 7240 5410 PRODUCTION 584 4-1/2" 12.6# 13Cr80 12303 - 12887 10699.24 - 11141.75 8430 7500 Perforation depth: Measured depth: 12760 - 12853 True Vertical depth: 11045.17 - 11116 - SCANNED JUL 1.8 2007 - - Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13C r80 40 - 12303 Packers and SSSV (type and measured depth) 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 1127 10457 12257 12303 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 1589 1620 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 34305 2052 0 35010 2132 0 15. Well Class alter proposed work: Exploratory Development w 16. Well Status after proposed work: Oil W Gas WAG Tubing pressure 792 793 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Data Engineer Printed Name Date 7/13/2007 JUL 1 8 2D07 #7J;?onIY . . " '" NS22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS I 1 DIESEL 1 TOTAL ~11'* ' t . . ~1f~1fŒ illJ~ ~~~~[K(~ . AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration Alaska PO Box 196612 Anchorage, AK 99519-6612 ~ aO}~~ Re: Northstar Field, Northstar Oil Pool, NS22 Sundry Number: 307-175 5G~tNNED MAY 3 1 2007 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thi~ day of May, 2007 Encl. Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 1. Type of Request: 3. Address: D75 ~3.1/1 STAT~F{C~~~~1 .s~ RECEIVED AIlKA OIL AND GAS CONSERVATION COM.ION . ~&..~õ\01 tI!!. APPLICATION FOR SUNDRY APPROVAL jß MAY 2 ~ Z007 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development ~ a a Stimulate D Time Extension DAnchorage Re-enter Suspended Well 0 5. Permit to Drill Number: Stratigraphic 0 Exploratory 0 Service 0 6. API Number: 50-029-23128-00-00 202-2230 , Anchorage, AK 99519-6612 8. Well Name and Number: 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer Descriotive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 11. Total Depth MD (ft): 12887 Casing SURFACE INTERMEDIATE LINER PRODUCTION Perforation Depth MD (ft): 12760 - 12818 Packers and SSSV Type: 12. Attachments: NS22 OCSY-0181 ( No 0 10. KB Elevation (ft): 11. Field/Pools(s): 56.51 KB . NORTHSTAR Field / NORTHSTAR OIL Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11142 , 12860 11121 NONE NONE Length Size TVD Burst Collapse 3663 13-3/8" 68# L-80 44 3707 44 3413 4930 2270 10638 9-5/8" 47# L-80 42 10680 42 9471 6870 4760 2012 7" 26# L-80 10457 12469 9292.55 10825 7240 5410 584 4-1/2" 12.6# 13Cr80 12303 12887 10699.24 11142 8430 7500 Perforation Depth TVD (ft): 11045.17 - 11089.32 Tubing Size: 3-1/2" 9.2# Tubing Grade: 13Cr80 Tubing MD (ft): 40 - 12303 Packers and SSSV MD (ft): 1127 10457 12257 12303 13. Well Class after proposed work: Exploratory 0 Developm ent ~ Service 0 6/4/2007 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by \.:Jcuy r-rt:ule 564-4944 Commencing Operations: 16. Verbal Approval: Commission Representative: Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Signature Contact Robert Younger Production Engineer 5/21/2007 564-5392 COMMISSION USE ONLY Phone Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: <30 '1- I ~5 Plug Integrity 0 Other: Subsequent Form Required: Approved by: BOP Test 0 Mechanical Integrity Test 0 Location Clearance D Form 10-403 Revised 06/2006 RIGINAL APPROVED BY THE COMMISSION Date: $-3 -() IYnS ...../ ~k~?ì 0+. t:~~ f) ,Submit in Duplicate ~..:.:.:.:.:..:.. ....I )::... .... RDIU ~AWIIDftUlO&IIIIÎ' . . .ßo PERFORATING PROCEDURE Ver 40 C6j04/01 Well: Date: NS22 ,----------------------~ 05-18-07 API #: 5O-029-23128-0( --------------_. ·_·_-_'~;"_-_-_....-_-.-_-_·.·_v_-.-_-_-_-_- .----------------------- Prod Engr !.<?_~e;r.t _'(~':Ir:$J~! _ . ~~~<:IYr: !.i~c:~~~~ . Office Ph: Home Ph: Cell Ph: 564-5392 ~------------------~ 677-2599 ~------------------- 830-4920 H2S Level: ---------------------- e Antic!.e;~! ~------------------- CC or AFC:. _ _ _ _ _ _~~f.!-_~~_I,,2.~ _ _ _ _ _ _ Detail Code: _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ __ _ _ _ _ _ __ _ __ _ _ _ _ _ _ __ Description: . Ç>rift. 1'.0. TÇ>. v.-'!th. Ç>!Jrn.r.n.Y.?'l!t),. p'~~?rÇ1!~. . . .......... .. . ... ... WBL Entries Work Description I Drift to TD with Dummv Gun ¡Perforate from 12,833'·12,853' MD I ¡ lOR 750 750 I I Type S E I I Well Obiectives and Loaaina Notes: Due to NS22's production decline following the 2004 stand alone scale inhibition treatment, a combination acid/scale inhibitor treatment was completed in August 2005 to remove any scale that had formed and to ensure delivery of Schlumberger's L66 scale inhibitor. A slight bump in production was noted. The March 2006 acid treatment (with no L66) showed a similar small bump. Following a January 2007 acid treatment, no bump in production was noted. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by perforating additional reservoir. The perforations are closer to the oil water contact (OWC) although there will still be 41'TVD from the OWC. We are currently perforated 67' above the OWC. 15'ofstandofl from existing perforations is included so a plug can be set in the case that water production dramatically increases. ./ Please note that the perforations will be dependent on the drill. In the event we are unable to get to the proposed perf interval, the perforation interval will be adjusted accordingly. / Please contact Bob Younger with any questions, comments, or concerns - 564-5392 (w); 830-4920 (c); 677·2599 (h). Attachment: Reference Log with annotated perforations. Reference Log Log: Jew.e.11)'. ~.R./~.C.~ Date: ....E2.4f?QQ~ Company:~q~I!I!.Tl~e.r9~! Depths (from-to) .. .1.2.,~.3.:r.. -. J?,~?~'.. Tie in Log .J~)N.e.lry.~.R.l.CCL . _ ?-!?!?-PP5J. ~q~I!I!.Tl~e.r9~r Depths (from-to) . .1 ?,~~~.'.. -.. g~.5.3.'.. AddlSubtract to the tie-in log to be on depth with the reference log. feet Feet 20' SPF 6 Orient. Phasing ..6.º~ .. 0 Zone AdlRellperf .IY!s.h.a.k. .... ....MP.e.rt......... ........-...'... ------------ ----------- ---------- ._--------- .--------. .-----------------------------. _...-....'..-.... .................. ..'...'...'.'..... .........-.--.. .................. o o o ....-....,..,............................-....'. ----------_. ----------- ---------- .---------- .--------. ------------------------------- .'...'....'...'.'.. ...'.'.......-...-..... .........-.-...-.-. .-.......-...'....... .-.'.-.........'. ..._'.'.'.'.'.'..._..'...'...-...~-~--... Gas Jetting Expected? No At what Depth? 2306 PJ ...,.........-...-.-.-..... 17.7 ._--...--...------. N/A .....-.'...'...-.-... Requested Gun Size: .. "~'??. . . Charge: Desired Penetration: Entry Hole Diam: _ _.. q.5J.... Is Drawdown Necessary/DesiredJUnnecessary During Perforating .~~........................................................ OfISCfibfl below how '0 achieve drawdown (chfICk wi Pad 0pMa'or to IIfHfJ jf ntlC8Sllary piping ill inslJ1Hfld) (e.g. N2 Lih. Hardline Uft Gu, au Lift, Flow WøI1, Backßow Through Drain or Hardh'ne) .---------------------------------------------------------" Tie in to Jewelry @ Minimum ID: WLEG Depth: MD .......'.'.'.'...'.-. ____~.?p__. _In ___'!.~,~P!l___ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ .~~-..._.......'.'...'.'....'._..-.'._--.._-.'....'.'....'.'.'..'._--..-.-.............. .. __. ~~!?")~~-'::J!p.PJ~ __ m @.!?c2.9.5.'MD m_~.p___.in 12.6# 13-CR Liner .g~qL MD .!!!qQ'. SS .::~'!.qq.... psi Last Tag: .. ....1.g,~?9.ft SLMD on .Y?;4!~ºº~ . Well: Date: NS22 Perforation Summary API #: 50-029-23128-00 ....................... .------------------- On-Site Prod Engr: . .,.....,.....,...,.,. PBm ......... .... ....... General Comments: . '. '. '. '. ~ '. ~ ~ " ~ '. '. '. '. '. '. ~ " .'. '. '. " ~ '. ~ ~ '. ~ ~ ~ '. '. '. .. '. '. '. .. '. .. .. '. '. ~ '. . ........-.-...-...... ...........-...-...-.....-.-......,.........-.-...............,.,.,.................-.....-.-.....-...-.-...-.-...,...,.,........ ...-.....................,.....,.,.....,.,.-. Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Feet SPF Orient. Phasing Zone Apert/Reperf ..,.............. 00 00 o ............. ... ..... ......... .... ....... ........... ..... ...... ......... . '. '. '. '. '. ~ ~ '. '. ..... ......, ........... .... ...... ......... .. ...... ........... ........... ................,.. .................. .................... .................. ................. ~ JEWELRY lOG CD GAMMA RAY / CCl -1 :5 w ~ ~ z w ~ 0 1258' NSL & 646' WEL Belt.: KB. 56.5 1ft: ¡::: D.. a: CD ~Z 0 ~ ~ AT SURFACE G.L 15.9 ft -1 CD CD -1 90 CD D.F. 56.5 ft :r: :r: z D..- Ii: Ii: Ò) g ~5 Permanent Datum: MSL 8ev.: Oft 0 0 10 cb N ~9 z z or- Z Log Measured From: RKB 56.5Ift above Perm. Dalum >. Drilling Measured From: RKB ~ r::: r::: 01 0 as :::J ii D- e 'U E Section Township Range "i) 0 0 0 8 w ¡¡: .....I 11 13N 13E -,'-- Casing Fluid Typø SaJìn~ Dens' Fluid Level BITlCASINGlTUBING STRING ....,---- Bit Size From ,----......_._--.._--_.._~-- To CaSin !Tubing, Biæ \y~ht Grade .---.....-----.---. From ___H....___._._ To Maximum Recorded Temperatures 1~~i~~~:==J L~O~~~ __~~5!~.!3Y__..______ Witnes$ed B ,_,.',,,.....~_._·A_ ...... ··-"'_·H·'___-___ ~_~~.·.__H.·n__·__"'..........._.~~_.·__~",,"""", 6.125 in 12486 ft 12887 ft 4.500 in 12.13 Ibm/ft _"^...=.="'~··Nm..v_·.. ,_....,___. ___.·._.__.·_·...........~..........N.'·_....,.___~ _···""_-...AA..w·'···m·~_.. W.~~'·_·A~_H.""-'_~, ".,.."""""-..,,............-.- 1:30 . > II '- I I I r I I I· . ..... /' ,L:- - - - - I œ--: I' '" J 1 4( I t=$ \ ) ! . ¡ I ""- m r I I f I r ¿ '\. - - - - - - - - = T T =~ 3 Discriminated CCI.. (CClD) M Gama- lGfU o ~ =t=1 I II ; : ---- - I I ! 1 100 1: I ! I , , . · t I r B I , · ~ · , - · - ¡ . - -1 - I , - - - B . 12700 I I I I ~ - - ;.--! . ·1 $~ - - - ~ - - 2800 - - - - - - ,1 i Comuuted CClICCLC) (V) PIP SUMMARY ~ I I , 1 I . I · , , . , II ¡ -. . ~ :EE ~ ~- I , I ~ I "·k :þ:::J I j.~ ..~... .I~~!'~'?!I.!1].~~>'............. (LBI=) 0 --3 TREE = ABB-VGI5-1/8" . Sa NOTES: ***3-1/2" CHROME TBG & 4-1/2" WELLHEA D"= . ABB.vGI13-5/8" MULTIBOWL 5K NS22 C E LNR*** NOTE: MMS WELL ACTUATOR = KB. ELEV = 56.1' BF. ELEV = 40.2' (CB 15.9') P-- KOP= ...!.. 1 1127' H3-1/2" TRM-4E SSSV, ID = 2.813" I ... ........... ... ... ... Max Angle = 43 deg @ 11377' Datum MD - Datum TVD = 113-3/8" CSG, 68#, L-80 BTC, ID = 12.415" I 3707' ~ ... GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LA TCH PORT DATE ~ 1 5032 4562 29 Minimum ID = 2.75" @ 12295' 2 5910 5335 28 3-1/2" XN NIPPLE 1 TOP OF 7" LNR I 10457' I rg 19-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" I 10680' ~12S ~ - I 12211' H3-1/2" FIBER OPTIC TRANSDUCER I - 112223' ELM H3-1/2" FIBER OPTIC TRANSDUCER I I I 12236' H3-1/2" X NIP, ID = 2.813" I . ~ ~ 1 12257' !-iT' PKR, 13 Cr I I I 12284 ' 1-13-1/2" X NIP, ID = 2.813" I 1 TOP OF 4-1/2" LNR I I . 12295' H 3-1/2" XN NIP, ID = 2.75" I 12303' I- ~/ 18 13-1/2"TBG,9.2#/ft,13CRVAM-ACE, 12308' '" r 12308' H SELF ALIGNING MULES HOE, ID = 3.85" I 0.0087 bpf, ID = 2.992" 17" LNR, 26#, L-80 Hydril 521, ID = 6.276" I 12469' ~ ~ 1 H ELMD TT NOT LOGGBJ? I ~ORA~ONSUMMARY REF LOG: GR/CCL 01/24/03 ANGLE AT TOP PERF: 40 @ 12760' INrrlAL PERF - CHARGE: 2306 POWERJET, HMX, 6 SPF ÆNETRATION: 22.8", HOLE: 0.27", PHASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-1/4 " 6 12760 - 12818 0 02/02/03 PBTD I 12860 elm' 1~-1/2" LNR, 12.6#, 13CR V AM-ACE, 12887' I 0.0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 01/27/03 MJF FINAL COM PLETION WELL: NS22 02/07/03 MJF ADD PERFS PERMrr No: '2022230 11/04/05 BJM NEW FORMAT API No: 50-029-23128-00 02/15/06 RAClPAG SAFETY NOTE- MMS WELL BP Exploration (Alaska) 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: ~ . ST ATE OF ALASKA J:/.p.ð1 ALAS OIL AND GAS CONSERVATION COMM.N REPORT OF SUNDRY WELL OPERATIONS o o o I \.L. VL.I oJ L.LJ FEB 1 2 2007 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate 0 Other 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2230 / Alaska Oil & Gas Cons. Commissi~ nc 3. Address: Exploratory Service 6. API Number: 50-029-23128-00-00 / 9. Well Name and Number: 56.51 KB NS22 / OCSY-0181 11. Present Well Condition Summary: 10. Field/Pool(s): NORTH STAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured 12887 true vertical 11141 .75 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured true vertical 12882 11137.95 feet feet Casing SURFACE INTERMEDIATE LINER PRODUCTION Length 3663 10638 2012 584 Size MD TVD Burst Collapse 13-3/8" 68# L-80 44 - 3707 44 - 3412.71 4930 2270 9-5/8" 47# L-80 42 - 10680 42 - 9471.3 6870 4760 7" 26# L-80 10457 - 12469 9292.55 - 10825.09 7240 5410 4-1/2" 12.6# 13Cr80 12303 - 12887 10699.24 - 11141.75 8430 7500 Perforation depth: Measured depth: 12760 - 12818 True Vertical depth: 11045.17 -11089.32 - ~NEDfEB'16 2007 - Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13Cr80 40 - 12303 Packers and SSSV (type and measured depth) 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 1127 10457 12257 12303 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: T/I/O=750/40/165 WHP=600NACNAC 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 2169 2137 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 30210 2268 0 30084 2302 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil ~ Gas WAG Tubing pressure 803 803 Service x Contact Robert Younger WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-413 Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date 2/6/2007 d 04/2006 0 R J G J N A L >")-h v Submit Original Only . . NS22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/29/2007 Acid Treatment - Job Prep, Stand by for E-line rig job in progress Continued 1-30-07 WSR 1/30/2007 T/I/O=750/40/165 Acid Treatment - Pickle tbg w/11 bbls 75*F 90:10 DAD (12% HCL) (10% Xylene), 74 bbls 100*F seawater & 28 bbls 90*F diesel. Soaked for 1 hr, flow back to well clean up tank. Pumped following Acid Treatment per procedure. 35 bbls 75*F 12% acid, 65 bbls 80*F filtered 2% KCL overflush (5' radial displacement), 86 bbls 100*F seawater displacement & 28 bbls 80*F diesel displacement/under-balance. Turn well over to op's for flow back/2- 6 hr tests as per procedure. Final WHP's=600/vac/vac *** Job Complete*** FLUIDS PUMPED BBLS 65 FILTERED 2% KCL 86 SEAWATER 28 DIESEL 35 12% HCL ACID 214 TOTAL 0.5% A261 CORROSION INHIBITOR 4 PPT A179 CORROSION INHIBITOR 8 PPT A153 CORROSION INHIBITOR 0.5% W060 ANTI-SLUDGE 0.5% W54 NON-EMULSIFIER 0.2% F103 SURFACTANT 20 PPT L581RON CONTROL . . SARAH PALIN, GOVERNOR AIASIiA. OIL AlO) GAS CONSERVATION COMMISSION· 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS22 Sundry Number: 306-413 SCANNED JAN 0 B 2007 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this-¥, day of January, 2007 Enc!. dOd-8g3 ¡;:¡;t::1' 1.l'?J /7 STATE OF ALASKA ~ /~/{} 1. ALA" &6ND GAS CONSERVATiON ¿OMMI N APPLICATION FOR SUNDRY APPROVAL ¡f;t. I?~C~ q-;, o£' IV€,I' 4/; t.::C lJ 20 AAC 25.280 fa.fI J. f)~ 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U WaiverU!l¡l ~ cSfh~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 4 ßí1s Co Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 I1C/¡Ofa,,~S' COt¡z 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: I': BP Exploration (Alaska), Inc. Development ~ Exploratory 0 202-2230 3. Address: P.O. Box 196612 Stratigraphic 0 Se rvice 0 6. API Number: Anchorage, AK 99519-6612 50-029-23128-00-00 7. KB Elevation (It): 9. Well Name and Number: 56.51 KB ~ NS22 8. Property Designation: 10. Field/Pools(s): OCSY-0181 . Northstar Field / Northstar Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (It): ITotal Depth TVD (It): /Effective Depth MD (It): Effective Depth TVD (It): IPlugs (measured): /JUnk (measured): 12887 11141.75 12860 11121.23 None None Casing Length Size MD TVD Burst Collapse Surface 3663 13-3/8" 68# L-80 44 3707 44 3413 4930 2270 Production 10638 9-5/8" 47# L-80 42 10680 42 9471 6870 4760 Liner 2012 7" 26# L-80 10457 12469 9292.55 10825 7240 5410 Liner 584 4-1/2" 12.6# 13Cr80 12303 12887 10699.24 11142 8430 7500 Perforation Depth MD (It): Perforation Depth TVD (It): Tubing Size: Tubing Grade: Tubing MD (It): 12760 - 12818 11045.17 - 11089.32 3-1/2" 9.2# 13Cr80 40 - 12308 - - - - Packers and SSSV Type: 3-1/2" TRM-4E SSV Packers and SSSV MD (It): 1127 7" Liner Top Packer 10457 7" Baker 13Cr80 Packer 12257 4-1/2" Liner Top Packer 12303 12. Attachments: Descriptive Summaryof Proposal ~ 13. Well Class alter proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Developm ent ~ Service 0 14. Estimated Date for 15. Well Status alter proposed work: Commencing Operations: 1/5/2007 Oil ~ Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Prepared by Gary Preble·564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature ,qÄ~~ Phone 564-5392 Date 12/22/2006 f / " COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: l~ 0 - 4r; Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: ~ () '-\ (Z ~COMMI~IONEA APPROVED BY Date: /-~dr Approved by: THE COMMISSION V J - 'SSio/ Form 10-403 Revised 7/2005 8Ft iì ZOOl Submit in Duplicate · No portion of the bel.ork should be performed w/out f.taking time to ensure , No Accident 0 harm to People, and No damag the Environment To: Jerry Bixby/Clark Olsen - Well Operations Supervisor December 15, 2006 From: Robert Younger/Carolyn Kirchner - Northstar Production Engineer Subject: NS22 Bullhead Acid Treatment AFE NSFLDWL22 MMS WELL Please perform an acid stimulation on NS22 per the below procedure including a pickle and fullbore acid/scale inhibition treatment: Est. Cost: $100 M Est. lOR: 100 BOPD Type lOR PR N DSWL AFE Job Description F 100 NS22 NSFLDWL22 Pump Acid Treatment & Scale Inhibition Treatment (SIT) Current Status: Producer last Test: 12/04/06: BOPD: 1,991, BWPD: 2,263; MMCFPD: 32.66 Max Inclination: 43° at 11,377 md; 40° at Perfs Max Dog leg: 4.6 deg/100' at 321' md Minimum 10: 2.75" @ 12,295' md, 3.5" XN Nipple last TO tag: 01/24/03: tag: drift w/ 3.625" Cent, CCl to 12,860' last Downhole Op: 02/01/03: Drift with 2.72" CENT TO 12,824' SlM, ( NOTE: Set down at 12,308' due to possible trash ). Perforate with 2306 PJ HMX gun, 6 spf. intervals 12798'-12818, 12778'-12798', 12760'- 12778' latest H2S value: None anticipated Due to NS22's production decline following the 2004 stand alone scale inhibition treatment, a combination acid/scale inhibitor treatment was completed in August 2005 to remove any scale that had formed and to insure delivery of Schlumberger's l66 scale inhibitor. The proposed acid treatment is an attempt to remove any scale that may have formed in NS22 since its last treatment, April 6, 2006. Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. RU pumping equipment. No portion of the belo.ork should be performed w/out fi.aking time to ensure . No Accident 0 harm to People, and No damag the Environment 4. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface when the pickle is produced back. 5. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 6. PT Dowell surface lines to 5000 psi Pickle 7. Pump the following fluids to pickle the production tubing at 3 - 4 bpm, 3500 psi max pressure. After about 98 bbls have been pumped into tubing, slow pumping rate to minimum pump rate around 0.25 bpm. Allow pickle to soak for 1 hour. a) 11 Bbls DAD acid b) 74 Bbls seawater c) 28 Bbls diesel 90:10 DAD Acid (12% HCL) to contain: 0.6% A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control 0.5% W60 Anti-sludge 8. After soaking, produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 113 Bbls. Acid Treatment 9. Pump the following treatment at maximum rate or 3500 psi max pressure. When the acid first hits perfs, slow pump rate to 1 BPM for Ÿ2 of acid volume then resume pumping at maximum rate. a) 35 bbls Acid b) 65 bbls 2% filtered KCI (Overflush for 5' radial displacement) c) 86 bbls Seawater (for.displacement) d) 28 bbls Diesel (for displacement and under-balance) Acid Description: 12% Acid to contain: 0.5% A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.5% W060 Anti-Sludge 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control . No portion of the belo.ork should be performed w/out fi.taking time to ensure . No Accident 0 harm to People, and No damag the Environment Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. 10. RD Schlumberger. FLOWBACK PROCEDURE: 11. Following the treatment, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 214 bbls. After clean- up, divert back to the plant and get 2 6-hour tests. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to Robert. Y ounger@ bp.com. Procedure Contacts: Robert Younger WK: 564-5392 HM: 677-2599 Cell: 830-4920 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: tit .s/Z,7/tYh . STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic Stimulate [2] Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 202-2230 6. API Number: 50-029-23128-00-00 9. Well Name and Number: Exploratory Service 3. Address: 56.51 KB NS22 8. Property Designation: OCSY-0181 11. Present Well Condition Summary: 10. Field/Pool(s): NORTH STAR Field/ NORTHSTAR OIL Pool Total Depth measured 12887 true vertical 11141.75 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 12882 true vertical 11137.95 feet feet Casing SURFACE INTERMEDIATE LINER PRODUCTION Length Size MD TVD Burst Collapse 3663 13-3/8" 68# L-80 44 - 3707 44 - 3412.71 4930 2270 10638 9-5/8" 47# L-80 42 - 10680 42 - 9471.3 6870 4760 2012 7" 26# L-80 10457 - 12469 9292.55 - 10825.09 7240 5410 584 4-1/2" 12.6# 13Cr80 12303 - 12887 10699.24 -11141.75 8430 7500 Perforation depth: Measured depth: 12760 - 12818 - - True Vertical depth: 11045.17 - 11089.32 - - Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 4-1/2" 12.6# 13Cr80 13Cr80 40 - 12303 12302 - 12308 Packers and SSSV (type and measured depth) 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 1127 10457 12257 12303 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft MAY ,3 (I 2006 Treatment descriptions including volumes used and final pressure: see attached fluid summary 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 3089 3207 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 25372 2835 0 26611 3317 0 15. Well Class after proposed work: Exploratory D Development R1 16. Well Status after proposed work: Oil R1 Gas [] WAG Tubing pressure 803 791 Service x Contact Sharmaine Vestal WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signatu -L Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 5/15/2006 Form 10-404 Revised 04/2004 \/GlfVAL Submit Original Only .. . . ~. NS22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 4/6/2006 Acid treatment. Pumped treatment as per program. Well tender and control room notified to leave shut in 4 hour before flowing. 4/6/2006 T/I/O = 1800/vac/vac ACID TREATMENT Pumped 38bbls warm diesel for pickle, 42bbls warm diesel for treatment. FWHP's = 1600/vac/vac FLUIDS PUMPED BBLS 38 Diesel 47 12% acid 62 Seawater 65 2% KCL 212 TOTAL . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Matker.doc ((Ù~ / I ~Œt.' \::\.., I,! / ð \ I !. Ii: rù II i Ii' ,\ f I ;! '~:J'!\\LJ! ) Un .IF' Æ\ il ¿/~\ (~.:~.e I.!'W(.' b!E1\ I I U( i~ i~ [I II / i.:i ~ n ))'i i !~,\ / ';""'L\ ~ ~u L:::1,. " I U ~...' ~_J ~,. \ . ) AlASKA OIL AND GAS CONSERVATION COltDDSSION Robert Younger Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 I / I I ¡ ! / I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 &,0 if..-- ;)..')-0 Re: Northstar Field, NS22 Sundry Number: 306-063 ;'.r.",I'I'.\.'iMlt:r\ ~: ~\.~~.l\o~~Pj~~G- ¡ ~I ~\ f)nOh &"i ({~ 1.t.!J . ,~ Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. '--- Sincerely, n orman Chairman DATED this"'~y of February, 2006 Encl. bp ) ) ... ,\1'.'11. -.....~ ~.....- ~~- ~...- ....~ -F.... ..'+j§'- ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519·6612 (907) 561·5111 February 15, 2006 RECEIVED FEB 1 7 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage Dear Winton: Re: Sundry Notice for NS22 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS22 well. This well has exhibited decline and historical analysis of formation water indicates the ~. formation of CaC03 scale is likely. NS22 has responded fairly to the August 2005 acid treatment. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid treatment / · Flowback Sincerely, Robert Younger Production Engineer BPXA, ACT, Northstar 1. Type of Request: Z"·~l.- D~ \ STATE OF ALASKA ) AL ....kA Oil AND GAS CONSERVATION COMMI,-,JION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ~ ,,%-\I...l6A- 2-/ ¿I!¿OO£., ~ RECEIVED ÿ~ FEB 1 7 2UO.) Perforate U Aff8k&tÐil& Gas Cons?L;¡8fr~~ ssÜ:m Stimulate [2] Time Extension D Anchorage Re-enter Suspended Well D 5. Permit to Drill Number: 6. API Number: 50-029-23128-00-00 /' Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend U Repair well D Pull Tubing D Stratigraphic 0 Exploratory 0 Service 0 202-2230 /' Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 56.51 KB NS22 /' 8. Property Designation: OCSY-0181 11. Total Depth MD (ft): 12887 10. Field/Pools(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 11141.75 Effective Depth MD (ft): Effective Depth TVD (ft): 12860 11121.23 Plugs (measured): None Casing Length Size MD / TVD Burst Surface 3663 13-3/8" 68# L-80 44 3707 44 3413 4930 Production 10638 9-5/8" 47# L -80 42 10680 42 9471 6870 Liner 2012 7" 26# L -80 10457 12469 9292.55 10825 7240 Liner 584 4-1/2" 12.6# 13Cr80 12303 12887 10699.24 11142 8430 Perforation Depth MD (ft): 12760 ~ 12818 / Tubing Size: 3-1/2" 9.2# /' Tubing Grade: 13Cr80 Perforation Depth TVD (ft): 11045.17 - 11089.32 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Packers and SSSV MD (ft): 1127 10457 12257 12303 Packers and SSSV Type: Commencing Operations: 16. Verbal Approval: / 13. Well Class after proposed work: Exploratory 0 Development ~ 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 2/28/2006 Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Robert Younger ...-- ¡?ç~ Junk (measured): None Collapse 2270 4760 5410 7500 Tubing MD (ft): 40 - 12308 / Service 0 Abandoned 0 WDSPL 0 Contact Prepared by Sharmaine Vestal 564-4424 Robert Younger Signature Production Engineer Date 2/14/2006 Phone 564-5392 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: .30(;, - t::Xø:3 :~ßDMS BFl F EB 2 :1 2006 Subsequent Form Required: l V - 4 Approved by: ~'~ ' /' COMMISSIONER J"J ~ Form 10-403 Revised 7/2005 0 RIG I r\~ t\ L APPROVED BY THE COMMISSION Date: 1-- ..t t- ,.()b Submit in Duplicate I \.......r..J V "-'I V II V ....11 ,'-", A BB- V GI13-5/8" MUL TIBOWL 5Ksrl ) 3. ELEV = =.. ELEV :: )P= 56.1 ' 40.2' ax 43 11377' 3turn MD = __,~._._,...,_._,..____,_,,,__,.,_.___.__._._._,.~.__,,_,,,___.",....._>-_"..""...__.__.·__."M"_____._·,,.._.._"'__.__.__"_.__._~._"__'. 3turn TVD = 3/8" CSG, 68#, L-80 BTC, ID = 12.415" 1-1 3707' ~ Minimum 10 = 2.75" @ 12295' 3..1/2" XN NIPPLE I TOP OF 7" LNR 1-1 18" CSG, 47#, L-80 BTM-C, ID = 8.681" 1-1 1 . 2$; r----M 10457' 10680' I TOP OF 4-1/2" LNR l--i 12303' 3-1/2" TBG, 9.2#/ft, 13CR V AM -ACE, --i 0.0087 bpf, ID = 2.992" 12308' IT' LNR, 26#, L-80 HycJril 521, ID = 6.276" 1-1 12469' ~ PERFOF\A TION SUMMA RY REF LOG: GRlCCL 01/24/03 A NGL E AT TOP PERF: 40 @ 12760' INITIA L PERF - CHA RGE: 2306 POWERJET, HMX, 6 SPF PENETRA TION: 22.8", HOLE: 0.27", PHASE: 60 DEG. Note: Refer to Pl'oduction DB for historical perf data SIZE SPF INTERVAL (MD) Opll/Sqz DA TE 2-1/4" 6 12760 - 12818 0 02/02/03 NS22 o L ----¡ :g] I ~I 1 / . C8: t,z IPBTD 1--i12860 elm 4-'1/2" U~R. 12.6#. 13CRVAM-ACE. --i 12887' ~ 0.0152 bpf, ID = 3.958" DATE 11/27/03 J2/07/03 1/04/05 REV BY MJF MJF BJM COMMENTS FINAL COM PLETION A DD PERFS NEW FORMA T DATE REV BY ~ ... COMMENTS SAFETY NOTES: ***3-1/2" CHROME TBG & 4-1/2" r 'PM E LNR**'k 1127' 1--i3-1/2"TRM-4ESSSV,ID=2.813" I .~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAT 1 5032 4562 29 2 5910 5335 28 I 12211' 1--i3-1/2" FIBER OPTIC TRANSDUCER I 112223' ELM 1-13-1/2" FIBER OPTIC TRANSDUCER 12236' 1-13-1/2" X NIP, ID = 2.813" I 12257' 1-17" PKR, 13 Cr I 12284' 1--i3-1/2"XNIP,ID=2.813" I 12295' 1-13-1/2" XN NIP, ID = 2.75" I 12308' l--i SELF ALIGNING MULESHOE, ID = 3.85" 1-1 EJJvlCì 1\101 NORTHST A R WELL: NS22 PERMIT No: 2022230 API No: 50-029-23128-00 8 ... - -<tJ' '- I \r L.. LJ 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA _ ALA all AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS o o o DEC 1 6 2005 Alaska Oil & Gas Cons. Commíssit 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development I;?i Stratigraphic fJ Stimulate [2] Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2230 6. API Number: 50-029-23128-00-00 9. Well Name and Number: Exploratory Service 56.51 KB NS22 OCSY-0181 11. Present Well Condition Summary: 10. Field/Pool(s): NORTH STAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured 12887 true vertical 11141.75 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 12882 true vertical 11137.95 feet feet Casing SURFACE INTERMEDIATE LINER PRODUCTION Length Size MD TVD Burst Collapse 3663 13-3/8" 68# L-80 44 - 3707 44 - 3412.71 4930 2270 10638 9-5/8" 47# L-8o 42 - 10680 42 - 9471.3 6870 4760 2012 7" 26# L-8o 10457 - 12469 9292.55 - 10825.09 7240 5410 584 4-1/2" 12.6# 13Cr8o 12303 - 12887 10699.24 -11141.75 8430 7500 Perforation depth: Measured depth: 12760 - 12818 True Vertical depth: 11045.17 - 11089.32 Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13Cr80 40 - 12308 Packers and SSSV (type and measured depth) 3-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 1127 10457 12257 12303 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: '~ /.-' í~\i¡;';;1' "'?vi\3\, ./i¡¡.;-., C ~'l (ODS Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 3160 3436 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 18071 2874 0 18521 3110 0 15. Well Class after proposed work: Exploratory Development I;?i 16. Well Status after proposed work: Oil I;?i Gas fJ WAG Tubing pressure 766 779 13. Service x Signat~~ Form 10-404 Revised 04/2004 RBDMS 8Ft DEe 1 H: 7nn', WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 12/13/2005 Submit Original Only .. e e NS22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~~PfltIIYD»'''E,?~CJ'illJt. ',. 8/13/2005 ****Well Flowing Upon Arrival**** Acid/Scale Inhibitor treatment; pickle wellbore, spear in with 2 bbls meth followed my 7 bbls 12% HCl, displace with 62 bbls 80 deg fsw, 49 bbls 80 deg diesel. Produce pickle back to test separator and well clean up tank, flow back vol=107 bbls. Spear in with 2 bbls meth followed by 35 bbls 12% HCl with 10% l66 scale inhibitor, displace with 117 bbls 2% KCl with 10% l66 scale inhibitor - 65 bbls 2% KCl 76 bbls 80 deg fsw - 38 bbls diesel. Close companion valve and let HCl soak 4 hrs. Produce well to test separator and clean up tank (350 bbls). Test well post clean - up. FLUIDS PUMPED BBLS 203 2% KCL 117 2% KCL w/10% L66 76 Diesel 12% HCL w/10% L66, .6% A261 , 4% A201, 4ppt A 179, 8ppt A 153, 50ppt 35 L41, .5% W54, .2% F103, 20ppt L58 7 12% HCL 438 TOTAL ~ 1ì!®,ìT I~ Œ) ~!JlJ IJ ~ I'm ~ I iJ I ,J \~! ) lÃ8/\\, ¡-; l~,'\ {\~, il~7 {Àåi \ Ù"\\ [I 1'1'~"1 ,,~ II" ¡tl f , '\ 'I ,'-' II , , I, ~' '¡ ! f\) ~ Ul,J æJ U\~ JJlJ ) ~L-2-L3 ALASKA OIL AND GAS CONSERVATION COMMISSION / / FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 " "". r. .,·<¡''o.QE' '¡;"\ J~JL .~ €) "JOOh, ~:; li â,",ß~ h! ,t_1 l 1., (J t:.. " Re: Northstar NS22 Sundry Number: 305-169 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision 0, uperior Court unless rehearing has been requested. W S' ce , / ' , ¡ ~... '. 0 n . N hair DATED this-'L day of July, 2005 Enc!. bp ') ) ..\tf4~I. ......~ ~~. ~- ~~ ..~ -F....... .,~~~~~\~ ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 5, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS22 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS22 well. This well has exhibited decline and analysis of formation water indicates the formation of / CaC03 scale is likely. Last summer's acidizing campaign at Northstar was very successful. The procedure includes the following major steps: . Pickle the tubing ~ · Bullhead HCI based acid treatment (which includes scale inhibitor) · Flowback Sincerely, vrvl~~1 :;:ç ~ Mic~el J. Fra U£. Senior Petrole m Engineer BPXA, ACT, Northstar OR\G!N,AL VJ~A 7/7!ZðOS- RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL062005 APPLICATION FOR SUNDRY APPROV,AL. ,", ,"I~:-'\·-c" C .. 20 AAC 25.280 . \~~'aska Oillaa, ons. ommlSSlon Anchorage PeriorateD waiverD' OtherD StimulateŒ] Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 202-2230 /' StratigraphicD Service D 9. Well Name and Number: NS22 /' 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WEll CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11085.0 12882 11082.0 Size MD TVD ) STATE OF ALASKA 1. Type of Request: Suspend 0 D D Operation Shutdown D Plug Periorations D Periorate New Pool 0 Abandon 0 D D Repair Well Pull Tubing Alter Casing Change Approved Program 2, Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Development Œ] 3, Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.51 KB 8, Property Designation: OCS-SY0181 11, Present Total Depth MD (ft): 12887 Casing length SURFACE INTERMEDIATE LINER PRODUCTION top bottom top 3663 13-3/8" 68# l-80 44 3707 42.0 10638 9-5/8" 47# l-80 42 10680 56.5 2012 7" 26# l-80 10457 12469 9292.6 584 4-1/2" 12.6# 13Cr80 12303 12887 10699.2 Perioration Depth MD (ft): 12760 - 12818 Perioration Depth TVDss (ft): 10989 - 11033 Tubing Size: 3-1/2 " 4-1/2 " ) /' Exploratory D 6, API Number /' 50-029-23128-00-00 Plugs (md): Junk (md): None None Burst Collapse bottom 9471.3 4930 2270 56.5 6870 4760 10825.1 7240 5410 11141 .8 8430 7500 9.2 # 12.6 # Tubing Grade: Tubing MD (ft): 13Cr80 40 13Cr80 12302 12302 12308 Packers and SSSV MD (ft): Packers and SSSV Type: 7" liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" liner Top Packer 3-1/2" TRM-4E SSV 12. Attachments: 10457 12257 12303 1127 13. Well Class after proposed work: Description Summary of Proposal Œ] Detailed Operations ProQram D BOP Sketch D 14, Estimated Date for Commencing Operation: / ServiceD July 15, 2005 Exploratory D DevelopmentŒ] 15. Well Status after proposed work: Oil Œ] /' GasD PluggedD Abandoned D 16. Verbal Approval: Date: WAG 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Michael Francis 0# 0'Y(cJvvß. f ¿Ý~k> j A £ . l Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Printed Name Signature BOP TestD Mechanciallntegrity Test D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Michael Francis Title Phone Petroleum Engineer 564-4240 7/1/05 Sundry Number: .?~-~/ Location Clearance D lc; 4c4, RBDMS BFL JUL 1 I 2005 BY ORDER OF THE COMMISSION Date: ¥j/ DH.\J3.\.NA1- Form 10-403 Revised 11/2004 SUBMIT IN DUPLICATE TREE: ABB-VGI S 1/8" Sksi WELLHEAD: ABB-VGI 13-S/8" Multibowl Sksi ') 13 3/S", 6S#/ft, L-SO, BTC @ 3707' MD 3 1/2", 9.2#/ft, 13-Cr, Vam-Ace TUBING ID: 2.992" CAPACITY: 0.0087 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10680' MD 3.S" X NIPPLE, @ 12236' MD ID = 2.813" 3.S" X NIPPLE, @ 122S4' MD ID = 2,813 3,S" XN NIPPLE, @ 1229S' MD ID = 2.75 4,S" WLEG, @ 12308' MD Self Aligning Mule shoe ID = 3.8S" 7", 26#/ft L-80, Hydril 521 @ 12469' MD NS22 f"/ ')RIGINAL KB. ELEV = S6.1' KB-BF. ELEV = 40.2' CB. ELEV = 15.9' 3 1/2" TRM-4E SSSV @ 1127' MD w/3 1/2" "X" PROFILE=2.813"ID ~ .. 3 1/2" GLM @ 5032' MD (4562' TVD) 3 1/2" GLM @ 5910' MD (5335'TVD) .... j ~ - 7" LINER TOP @ 10457' MD J E- 3.S" Fiber Optic Transducer @ 12223' MDelm, 10646' TVDrkb, 10590' b- 7" ~:~SKER, 13 Cr @ 12257' MD, \, _ 106727VO"'b E 4.S" LINER TOP @ 12303' MD ~ ... ~RA~ONSUMMARY REF LOO: GRlCCL 1/24/2003 AI\GLE AT TOP FtRF: 40 deg \bte: Rafer to A'oduction œ for historical perf data klitial Perf - O1arge: 2306 A:JwerJet, fiv1X; Penetration: 22,8"; I-ble: 0,27"; A1ase: 60 deq SIZE SFf' I~AUvO I~AL lVD q:,n/Sqz DA.TE 2,25 6 12760' -1~8' 11053' -11097 q:,n 21212003 PBTD @ 12860' MD elm 1/24/2003 Note: STICKY BOTTOM TD @ 12887' MD ~ ~ 4.S", 12.6#, 13Cr Vam Ace DATE 11/18/02 01/06/03 01/27/03 02/07/03 REV. BY BMH JAS MJF MJF COMMENTS ""N S22 proposed NS22 Completed to Top SAG Proposed Perfs Post Perfs Northstar WFI I : NS?? API NO: 50-029-23128-00 BP Exploration (Alaska) ?. M",^- À..M f".' DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2022230 Well Name/No. NORTHSTAR UNIT NS-22 Operator BP EXPLORATION (ALASKA) INC ) £1 lAC!. :2; /J O~;Z D ~ J..-- r API No. 50-029-23128-00-00 MD 12886:/' TVD 11149 Completion Date 2/2/2003;/ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes --- ----------- DATA INFORMATION Types Electric or Other Logs Run: GR, DIR, GYRO, RES, PWD, MWD Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~-~ Log/ Electr Data Digital Dataset Log Log Run Interval OH/ ""::- Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt Directional Survey 1 0 12887 Open 2/11/2003 ~ D Directional Survey 0 12887 Open 2/11/2003 '-··ED C ..4544 See Notes 0 12860 Case 2/28/2003 Jewelry log GRlCCL Depth determination E9' D Directional Survey 0 12486 Open 1/31/2003 ..... Rpt Directional Survey 0 12486 Open 1/31/2003 'a;y' C t..1--tS36 See Notes 445 12790 Open 3/20/2003 Digital Well Logging Data 'Ì~:: ~ nd uction/Resistivity 25 Blu 445 12790 Open 3/20/2003 nduction/Resistivity 25 Blu 445 12790 Open 3/20/2003 -fLOg --['Density ~. 25 Blu 1. f'12436 12854 Open 3/20/2003 Log Neutron 25 Blu 1 fJ1)) i:j 2436 12854 Open 3/20/2003 v/ . Log ~ensity f' 25 Blu 1 tv f12436 12854 Open 3/20/2003 - .~. I-L09 Neutron 25 Blu 1 l) 12436 12854 Open 3/20/2003 ----., ~ - \:....BerfÓ~ion 5 Blu 1 11980 12855 Case 3/20/2003 'L~ See Notes 5 Blu 11980 1285~e 3/20/2003 Jewelry Log / Gamma Ray '---- I / Casing Collar Locator LkPt' Report: Final Well R 0 0 ~ÿ28/2003 Located in the Well History File. Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022230 Well Name/No. NORTHSTAR UNIT NS-22 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23128-00-00 MD 12886 TVD 11149 Completion Date 2/2/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMA~N Well Cored? Y /(t~L) Daily History Received? (j/N ð/N Chips Received? ,~~ '------ Analysis Y 1 N Received? Formation Tops - -- ------ Comments: :,~- - ---, ~ Date: ¿). J.... MlM-4 > Compliance Reviewed By: -~ '~ ~ .,' ) ) Date: 05-27-2003 Transmittal #92651 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS23 05-09-2003 SCH 1 0 13981 MWD SURVEY RE(QRT/HARD,~OPYI DISKETTE f\..C") \":;:. ~l ~ ~ f)..rb)-drJ-:¡ NS 19 05-03-2003 SCH 14012 12550 JEWELRY LOG; ...... 0- \~á' NS10 03-25-2003 SCH 4850 8015 RST WFL-UP FLOW MODE; ~ NS19 05-05-2003 SCH 13140 14000 PERFORATING RECORD; NS06 04-09-2003 SCH 13000 13788 PERFORATING RECORD; -NS23 05-01-2003 SCH 11040 13333 PERFORATING RECORD; ?p3-cr:o( NS23 04-29-2003 SCH 13340 13212 DEPTH DETERMINATION SAMPLE BAILER;_,·· ~Ié) .. \ 0 \ NS06 04-11-2003 SCH 13025 13746 BAKER IBP SET RECORD; ~'--, \0 NS18 07-17-2002 SPERRY END OF WELL REPORT/MUDLOG: ;9.Dé)'-è)J:).j NS22 01-22-2003 SPERRY END OF WELL REPORT/MUDLOG: 3.~ -JlPt-f NS24 12-27 -2002 SPERRY END OF WELL REPORT/MUDLOG: ~~VV\.. ~l(J~~jV' Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center t~ECE'\/ED Ml\ y 2. U 2000 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 , . ...." ,'~. ...,....,. ·'..·...¡,I(~;·t-..ift¡~ Ala!Ý-s Cr. ~~ vd.i:. l,;,.:.,,¡¡,. \..{.;.... ¡~W" I~~:d¡~ I~..::: I ) BPXA WELL DATA TRANSMITTAL BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Lisa Weepie Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn:.Tim Ryherd MMS Attn: Doug ChorOlnanski Attn: Kristin Dirks (DNR) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchoragc, AK 99519-6612 } i Date: 05-27-2003 Transmittal #92651 bp ) ') Date: 03-20-2003 Transmittal Number:92597 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtoiohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS17 02-22-2003 MWD SURVEY REPORT; d Q;)-II"C) HARDCOPY/DISKETTE; NS12 03-08-2003 MWD SURVEY REPORT; ~o;J·-IIO HARDCOPY/DISKETTE; NS22 11-21-2002 SCH 445 12854 VISION RESISTIVITY; TRUE VERTICAL DEPTH LOG; V COMPOSITE FIELD PRINT; NS22 11-21-2002 SCH 445 12854 VISION RESISTIVITY; v' MEASURED DEPTH LOG; COMPOSITE FIELD PRINT; NS22 11-21-2002 SCH 445 12854 VISION DENSITY NEUTRON; r0 MEASURED DEPTH LOG; ~ COMPOSITE FIELD PRINT; V 'ê NS22 11-21-2002 SCH 445 12854 VISION DENSITY NEUTRON; G TRUE VERTICAL DEPTH LOG; ~ V COMPOSITE FIELD PRINT; NS22 02-02-2003 SCH 2 11980 12855 PERFORATING RECORD; V 2.25" 2306 POWERJET; NS22 01-01-2003 SCH 2 11980 12855 JEWELRY LOG; V GAMMA RA Y/CCL; t.J S ':1. ~ ./ o t -Jr,. 2oo"J SCJ..J or G I TAL.. I) AT A F'bA N5:J.~ H£I=. NO d,30(ÕL' J RECEIVED MAR 2 0 2003 AJa8fœ Q~ & Gas Cons. Commisston Anchorage Petrotechnical Data Centei- LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ) ) Date: 03-20-2003 Transmittal Number:92597 BPXA WELL DATA TRANSMITTAL ,~. ¡J,~ (./~ Please Sign and Return ne copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED fJiAR 2 0 2003 AJa6ka Of; & Gas Con Co . AnchOf!g~ 111lnlssion Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ,I / , 'ir" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 1259' NSL, 646' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1405' NSL, 3318' WEL, SEC. 01, T13N, R13E, UM X = 662314, Y = 6036512 10. Well Number At total depth 1497' NSL, 3283' WEL, SEC. 01, T13N" R13E, UM X = 662349, Y = 6036607 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Northstar Unit KBE = 56.51' OCS·Y0181 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/21/2002 (1/19/2003 2/2/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12886 11149 Fr 12882 11146 FT a Yes 0 No 22. Type Electric or Other Logs Run GR, DIR , GYRO, RES, PWD , MWD 23. CASING SIZE 20" 13-3/8" 9·5/8" Classification of Service Well i7C" ~:'-',.~,':,::.:;;~1. I~t,~~.'::r~ , " i _,,\ ,'': ~: ~~, 'Q.,~\; ~~L": " ..;~' "..,:., ""'~"'.'-"""", ~~~"",,1tl.\' '''1'",'' ',,, 9. X = 659827, Y = 6031032 7. Permit Number 202·223 8. API Number 50· 029·23128·00 Unit or Lease Name Northstar Unit " :j/\\C;, ì 2..:..2~,,:.C.3.( 99519.661~. , ,. ~f[,!~~1I;·.t.:,~~ ~: ',.,... '. .ß,J).:; :,.".i,:~.:', NS22 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1142' MD 1545' (Approx.) WT. PER FT. 169# 68# 47# 26# 12.6# GRADE X·56 L-80 L·80 L-80 13Cr CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 201' 20" Surface 3707' 16" Surface 10680' 12-1/4" 10458' 12469' 8-1/2" 12303' 12887' 6-1/8" CEMENTING RECORD Driven 615 sx PF 'LI, 474 sx Class 'G' 720 sx Econolite, 565 sx Class 'G' 360 sx Class 'G' 100 sx Class IG1 AMOUNT PUllED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/4" Gun Diameter, 6 SPF MD TVD MD TVD SIZE 3-1/2", 9.2#, 13Cr80 TUBING RECORD DEPTH SET (MD) 123111 PACKER SET (MD) 12257' 25. 12760' . 12818' 11053' - 11097' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4414' Freeze Protected with 309 Bbls Diesel. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 3, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl 2/10/2003 4 TEST PERIOD 8690 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF 15.224 GAs-McF WATER-BBl 469 WATER-BBl CHOKE SIZE GAS-Oil RATIO 61 1.751 Oil GRAVITY-API (CORR) 0.812 ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPR E ( E i V' E No core samples were taken. r1AR -1 0 200·:1 f~J~m¡l Oil 81 Gæ ~n~~ C~~m]it~î~@¡m "'-i . .~¡~'I"~~:~'~¡¡i!f~,'mR~ .. ~:¡;_.s1in'_~'éij~., Form 1 0-407 Rev. 07-01-80 ',!80MS 8Fl G~ I\;Î~ 0 I 'J 1"··'1 '\ '.(. Submit In Duplicate ,'I 29. Geologic Markers Marker Name Measured Depth Top of Ugnu 5347' Top of Schrader Bluff 7148' Top of Kuparuk 10065' Kuparuk C 10326' Top of Sag River 12452' Top of Shublik 12632' Top of Ivishak 12730' ) ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4839' 6432' 8981' 9191' 10820' 10956' 11 030' RECEIVED MAR 1 0 200J ~OiI&.GaaCons. Anchõr. Commiaim 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak Off Integrity Test Summary. oing is true and c9rrect to the best of my knowledge Title Technical Assistant Date Dl ~ l 0 " () 2-=.') 32. I hereby certify that the f Signed NS22 Well Number 202-223 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Allen Sherritt, 564-5204 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ') Well: Field: API: Permit: NS22 Northstar Unit 50-029-23128-00 202-222 Accept: Spud: Release: Rig: 11/21/02 11/21/02 01/27/03 Nabors 33E POST-RIG WORK 01/31/03 PULL BALL & ROD, PULL SHEAR VALVE AT STA# 1, PULL RHC 02/01/03 DRIFT WITH 2.72" CENT TO 12,824' SLM, (NOTE: SET DOWN AT 12,308' DUE TO POSSIBLE TRASH) RIG DOWN SLlCKLlNE AND START GETTING READY FOR E-LlNE OPERATIONS. STEM TEST BOPS / PRESS TEST LUBRICATOR WITH TEST TOOLS- NO O-RING LEAKS ON TOOLS 02/02/03 RIH WITH GR AND CCL FROM 12850 TO 12100 FOR JEWERL Y TIE IN LOG, RIH WITH 20' X 2.25" HSD, 2306 PJ, HMX, 6 SPF, 0.27" DIA AND SHOOT INTERVALS 12798'-12818,127781-12798', .... 127601-12778' ALL SHOTS FIRED, WHP 750 PSI AFTER LAST RUN. RIG DOWN E-LlNE AND RIG UP SLlCKLlNE DUMMY OFF ST A# 1 02/03/03 FINISH SETTING DUMMY IN STA# 1/ BLED IA DOWN, GOOD TEST PULL SLlPSTOP Legal Name: Common Name: Test Date 12/9/2002 11/28/2002 12/7/2002 12/9/2002 NS22 NS22 Test Type FIT LOT LOT FIT Test Depth (TMD) 10,680.0 (ft) 3,706.0 (ft) (ft) 10,680.0 (ft) BPEXPLOAATION Leak-OffTestSumr'rlary Tes(DepthJTVD) 9,475.0 (ft) 3,411.0 (ft) (ft) 9,475.0 (ft) AMW 12.70 (ppg) 8.50 (ppg) (ppg) 12.70 (ppg) Surface Pi'èssure' 900 (psi) 600 (psi) (psi) 900 (psi) Leak Off Þi'e~slÏrEJ <aHP) 7,151 (psi) 2,106 (psi) (psi) 7,151 (psi) EMW 14.53 (ppg) 11.89 (ppg) 11.89 (ppg) 14.53 (ppg) ,-,' -- Printed: 2/3/2003 12:20:40 PM ) ) BPEXPLORATION Paget of 22 Opera~i.()nsSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From -'-To Hours Task Code NPT Phase Description. of, Oþerations 1/16/2002 00:00 - 0.00 TA SURE 11/21/2002 00:00 - 01 :30 1.50 MOB P PRE PU and clean cellar area. 01 :30 - 03:30 2.00 MOB P PRE Prepare for rig move. Obtain permit. 03:30 - 05:00 1.50 MOB P PRE PJSM- Moving rig. - Move rig fl NS21 to NS 18. 05:00 - 06:30 1.50 MOB P PRE Remove rig mat from NS 22 & stage well head equipment in cellar. - Lay herculite. 06:30 - 09:00 2.50 MOB P PRE Move fl NS 18 to NS22. - Spot and level rig. 09:00 - 09:30 0.50 MOB P PRE PJSM. MU Sea Wate Line. - Other side still frozen, will thaw later. 09:30 - 11 :30 2.00 MOB P PRE Fill pits wI Seawater. Close in cellar, berm rig, and lower stairways. 11 :30 - 12:00 0.50 RIGU P PRE ****Accept rig @ 0900 hrs. **** NU Btm section of surface riser & test tl 2000 psi f/15 min. 12:00 - 16:00 4.00 RIGU P PRE NU Upper riser & Pitcher nipple. 16:00 - 16:30 0.50 RIGU P PRE Fill riser w/ Sea Water and check for leaks. 16:30 - 18:00 1.50 DRILL P SURF PJSM. MU BHA#1. 18:00 - 19:00 1.00 DRILL P SURF Drill out conductor. Drill ahead to 230' md. 19:00 - 20:00 1.00 DRILL P SURF PJSM. RU wireline for Gyro. 20:00 - 21 :00 1.00 DRILL N DFAL SURF Troubleshoot Gyro tools. 21 :00 - 21 :30 0.50 DRILL P SURF Run Gyro. Initial survey @ 175' md, 2.73 deg inclin and 181.43 Azimuth. Frequent Surveys because Gyro indicating high anglel High Doglegs in Conductor. 21 :30 - 22:00 0.50 DRILL P SURF Slide from 230' md to 241 md. 22:00 - 22:30 0.50 DRILL P SURF Run Gyro. 22:30 - 23:00 0.50 DRILL P SURF Slide from 241' md to 248' md. 23:00 - 23:30 0.50 DRILL P SURF Run Gyro survey. At 234.5' md, 3.33 deg inclination, 185.25 Azimuth. 23:30 - 00:00 0.50 DRILL P SURF Slide from 248' md to 274' md. 11/22/2002 00:00 - 07:00 7.00 DRILL P SURF Drill ahead 16" surface hole from 274' md to 510' md wi BHA #1. - AST= 1.1 hrs. - ART= 0.1 hrs - Gyro time= 2.6 hrs. In better shape directionally. Outside hardline for 500'-1000' md. 07:00 - 07:30 0.50 DRILL P SURF CBU. 07:30 - 10:30 3.00 DRILL P SURF POOH for BHA#2 (MWD). 10:30 - 11 :00 0.50 DRILL P SURF Drill ahead 16" surface hole from 510' md to 546' md wi BHA #2. 11 :00 - 12:00 1.00 DRILL P SURF CBU. Gyro. 12:00 - 13:00 1.00 DRILL N RREP SURF Find and fix leak in possum belly. 13:00 - 15:00 2.00 DRILL P SURF Drill and slide from 546' to 816' md. 15:00 - 15:30 0.50 DRILL P SURF Run Gyro. 15:30 - 19:00 3.50 DRILL P SURF Drill and slide ahead 16" surface hole from 816' to 1277' md. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Page 2 of22 Olperations Summary"Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task . Code NPT Phase Descri ptionof Operations 11/22/2002 19:00 - 20:00 1.00 DRILL P SURF Run Gyro. 20:00 - 20:30 0.50 DRILL P SURF Service Top Drive and drawworks. 20:30 - 23:30 3.00 DRILL P SURF Drill and slide 16" hole from 1277' to 1561' md. 23:30 - 00:00 0.50 DRILL P SURF Run Gyro. 11/23/2002 00:00 - 00:30 0.50 DRILL P SURF Drill ahead 16" surface from 1561' md to 1655' md. 00:30 - 02:00 1.50 DRILL P SURF Gyro. 02:00 - 02:30 0.50 DRILL P SURF Drill ahead f/1655' to 1749' md. 02:30 - 03:30 1.00 DRILL P SURF PJSM. RD Schlumberger and Gyrodata. 03:30 - 19:00 15.50 DRILL P SURF Drill ahead f/17 49' to 3725' md into SV-5 (Casing point + 19' rat hole). - Final projected inclination at TD is 29.42 degs. Azimuth 22.54 degs. - Overall average Rap 225 fph. - Pump hi-vis sweep every 400'. - Total Flow was increase to 1050 gpm. Screen blinding forced dropping flow rate for the last 375'. - TD parameters: 40 rpm w/13 K-Ibs torque; 730 gpm w/1480 psig on; WOB 35K Ibs. 19:00 - 21 :30 2.50 DRILL P SURF Pump 70 bbls hi vis weighted LCM sweep and circulate surface to surface. - Circulate 1X BU @ 750 gpm - Increase rate and circulate @ 1025 gpm for 1.5 x BU. Returns clean. 21 :30 - 22:00 0.50 DRILL P SURF Monitor well. 22:00 - 00:00 2.00 DRILL P SURF Pull 5 stds off btm (PU WT= 200K, RIH WT= 150 K Ibs). - Hole in good condition, pump dry job. Blow down TO. Continue POOH to HWDP. - Check Trip good. Max drag 20 K @ 2452'. Swabbing at DL's @ 1209' and 1020' md. Usual buildup of clay on tool joints on the way out 11/24/2002 00:00 - 04:00 4.00 DRILL P SURF Continue out of hole w/ BHA#2. -Stand back Drill Collars - LD BHA and make service break on stabilzer blades. - Bit graded 2-3-WT-A-E-I-NO-TD 04:00 - 05:30 1.50 DRILL P SURF Clear and clean rig floor. Remove bails and elevators. 05:30 - 06:30 1.00 CASE N RREP SURF Repair pipe shed hoist. 06:30 - 08:00 1.50 CASE P SURF PJSM. Rig up the floor to run 13-3/8" casing. 08:00 - 08:30 0.50 CASE P SURF PJSM on running 13-3/8" casing. 08:30 - 17:00 8.50 CASE P SURF MU float equipment to 12000 ft-Ibs torque, Bakerlock connections. - Circulate shoe-track volume. PU and RIH. Floats good. - Had to washlwork past 2506 ft. - Run 15 joints of 13-3/8" 68# L-80 wi cent floating, including shoe-track. - Continue Running 89 jts total 13-3/8" 68# L-80 BTC casing. MU torque average 8000 ft-Ibs. 17:00 - 17:30 0.50 CASE P SURF MU fluted hanger wi pup jt, landing joint, and land casing. - Install cement head. -Slack of weight when landing was 175 klbs( including blocks) 17:30 - 20:00 2.50 CASE P SURF Establish circulation and work rate up to 11.2 bpm @ 425 psig. Printed: 2/3/2003 12:21 :21 PM ) ') ·BP EXPLORATION Operati()nsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task 11/24/2002 17:30 - 20:00 2.50 CASE P SURF 20:00 - 20:30 0.50 CASE P SURF 20:30 - 22:30 2.00 CEMT P SURF 22:30 - 23:30 1.00 CEMT P SURF 23:30 - 00:00 0.50 CEMT P SURF 11/25/2002 00:00 - 02:30 2.50 CEMT P SURF 02:30 - 04:00 1.50 CASE P SURF 04:00 - 06:30 2.50 CASE P SURF 06:30 - 11 :00 4.50 WHSUR P SURF 11 :00 - 12:00 1.00 WHSUR P SURF 12:00 - 14:00 2.00 WHSUR P SURE 14:00 - 15:00 1.00 WHSUR P SURE 15:00 - 18:00 3.00 RIGD P SURE 18:00 - 19:30 1.50 WHSUR C SURF 19:30 - 00:00 4.50 BOPSUR P SURF 11/26/2002 00:00 - 02:00 2.00 BOPSUR P SURF 02:00 - 05:30 3.50 BOPSUR N RREP SURF 05:30 - 06:30 I 1.00 BOPSURP SURF 06:30 - 09:00 2.50 CASE P SURF 09:00 - 13:00 4.00 BOPSURP SURF Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Description of Operations - Getting cleanup at higher rate. PJSM for Cement Job. Switch to 75 bbls of Sea Water- Bicarbonate pill. Pump 5 bbls sea water. Pressure test to 3000 psig. Pump cement job as per plan: 1) Mix and pump 75 bbls of 10.5 ppg Alpha Spacer @ 6 bpm. 2) Drop bottom plug. 3) Start mix and pump 453 bbls (615 sxs) of 10.7 ppg lead cement @ 7 bpm. 4) Start mix and pump 97 bbls (470 sxs) of 15.9 ppg tail cement @ 5 bpm. 5) Drop Top Plug. Flush out top plug wi 25 bbls Sea Water from HALCO. - Switch to rig pump w/1 0.4 ppg NaCL brine for displacement. - Catch plug @ 800 strokes. - Displace @ 10 bpm. At 3400 strokes drop rate to 8 bpm. Good cement back to surface. Up rate to 9.0 bpm after turning on sea water and jetting wi Citric solution from trip tank. - Slow rate to 5 bpm @ 4950 strokes wi 950 psig prior to bump. - Bump plug at 5131 strokes (96.1 % pump eff calc) 541 bbls total displacement on HALCO meter. -Hold 1500 psi for 7 mins. Bleed off and check floats. - Prepare to rig down cement head. Remove casing elevators. Back out top section of landing jt. Pull master bushings. Drain and flush riser & flowline. PJSM. Change out bales and elevators. RIH wi DC's, TIW valve, HWDP, and DP to 1375' to displace brine from wellbore. PJSM. POH and LD 15 jts DP, 26 jts of HWDP, Jars, and 3- DC's. PJSM. LD Mousehole, ND riser & riser adapter. NU and test Multibowl WH to 2000 psig. PJSM. RU and fill well wi diesel- 30 bbls. Land and test hanger to 5000 psig. Fill hanger void with oil. Install cover on WHo Clean pits, reinstall cellar heater, clean up drip pan, service top drive, service drawworks, grease crown, and install cover on trip tank. ****Ice thickness to south-dictates plan change (Consult with Anchorage Engineering). Only 14" - need 18". PJSM. Change oil in top drive. Pull tubing hanger. PJSM. NU BOP stack. Mix mud for 12.1/4" intermediate hole, unload pipeshed of 4.1/2" tubing, bring 12.1/4" tools into pipeshed, and prepare for intermediate hole section. NIU BOP's. PJSM - Repair hinge seals on shear ram door. PJSM - Install test plug, test joint, & RIU to test BOP's. Clean rig while mixing mud. Test BOP's to 4800 I 250 psi for 51 5 min. Printed: 2/3/2003 12:21 :21 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Page 4 of 22 Q:perationsSunlmaryReport NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 pate From - To Hours Task Code· NPT 11/26/2002 13:00 - 20:30 7.50 BOPSURN RREP SURF 20:30 - 00:00 3.50 BOPSUR P SURF 11/27/2002 00:00 - 01 :30 1.50 BOPSUR P SURF 01 :30 - 02:00 0.50 CASE P SURF 02:00 - 03:00 1.00 CASE P SURF 03:00 - 08:00 5.00 CASE P SURF 08:00 - 09:30 1.50 CASE P SURF 09:30 - 11 :30 2.00 CASE P SURF 11 :30 - 13:00 1.50 CASE P SURF 13:00 - 13:30 0.50 CASE P SURF 13:30 - 14:30 1.00 DRILL P SURF 14:30 - 16:00 1.50 CASE P SURF 16:00 - 00:00 8.00 CASE N WAIT SURF 11/28/2002 00:00 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 18.50 CASE N WAIT SURF 1.00 CASE P SURF 1.00 CASE P 0.50 CASE P SURF SURF 3.00 DRILL P INT1 Description of Operations PJSM - change out upper IBOP. Test BOP's to 4800 /250 psi for 5/5 min. BID choke line. Pull test plug, install wear ring, & BID lines. PJSM - RIH wi 4 stds. DP PJSM - Displace 30 bbls. diesel back to trip tank and onto G & I through mud header line, by-passing G & I injection tanks and pumped directly downhole into NS-1 0 via G & I injection pump. PJSM - P/U BHA, orient MWD, change bend on motor, & change out 3 stab. sleeves. P/U 26 jts. HWDP & RIH. RIH to 3560' & wash down to 3615'. Circulate for casing test. Test 13 3/8" casing to 3500 psi & hold for 30 minutes. Drill out float collar. Circulate new mud displacing out 9.4 brine. No helicopters due to weather restrictions. Waiting on 9 5/8" casing to be slung to location. Have only flown 10 jts. so far and want to ensure this operation runs smoothly before drilling ahead. Notes: 1) Safety stand down to discuss remedies for future safety at Northstar. 2) Service top drive. 3) Grease all sheaves in derrick, crown, & drawworks. 4) Rehung derrick climber. 5) Clean & grease air slips. 6) Organize BOP parts room. 7) Remove links from drag chain. 8) Clean motormans room & general clean up of rig. 9) Circulating 5 min. every hour @ 50 SPM. Moving pipe every 3 hrs. Weather conditions kept helicopters grounded until 07:00. Moved personnel & then started slinging 9 5/8" to location. Refrained from drilling ahead until pipe slinging was well under way to ensure smooth operation. Notes: While waiting on weather 1) Perform maintenance on iron roughneck. 2) Plumb in new caustic hopper. 3) Chinking rig ( Sealing gaps for weather) 4) Safety stand down from 03:00 - 05:00. 5) Repair top drive oil light. 6) Troubleshoot link tilt air regulator. 7) Grease & repair agitators in pits. 8) General cleaning, scrubbing & organizing on rig. Drill out remaining cement in shoe track, rat hole & 20' of new 121/4" hole to 3745' md. CBU until MW in = MW out. 8.5 ppg Perform LOT to 11.9 EMW wi 8.5 ppg MW @ 600 psi. Pressure leaked off at 600 psi- repeated 3 times. Projected Kick Tolerance at TD is 64 bbls at a Pore pressure 0.5 ppg over Kuparuk Pore Pressure. Drill from 3745' to 4121' md in 12 1/4" hole w/9 5/8" XP motor Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Page 50f 22 Oiperations',SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2002 21 :00 - 00:00 3.00 DRILL P INT1 w/1.15 deg. bent housing. ART 1.56 hrs. AST 0 hrs. 11/29/2002 00:00 - 21 :00 21.00 DRILL P INT1 Drill 12 1/4" hole from 4121' to 6468' md. w/9 5/8" motor wI 1.15 deg bent housing. Notes: 1) Pumping hi-vis sweeps every 500' wi no visible increase of cuttings @ shakers. 2) Backreamingl wiping a little rough on the first 40 ft of each stand- might be due to the porcupine reamer. 21 :00 - 21 :30 0.50 DRILL P INT1 Service top drive. 21 :30 - 00:00 2.50 DRILL P INT1 Continue drilling ahead from 6468' to 6656' in Ugnu. Last survey @ 6577' Incl. 27.96, Az. 24.31. 11/30/2002 00:00 - 19:00 19.00 DRILL P INT1 Drill ahead in 12 1/4" hole wi 9 5/8" motor w/1.15 deg bent housing from 6656' to 7739' md pumping hi-vis sweeps every 500'. Notes: Survey @ 7661' incl. 28.20, Az. 24.67 Added 2 % lubricants before POH for next bit run. Stopped drilling in a sandstone to pre-empt any bit balling when drilling resumes. 19:00 - 20:00 1.00 DRILL P INT1 Pump hi-vis walnut I barofibre sweep & circulate 1 1/2 BU. Hole clean. 20:00 - 20:30 0.50 DRILL P INT1 Monitor well & POH wi 5 stds. 20:30 - 21 :00 0.50 DRILL P INT1 Pump dry job & B/D lines. 21 :00 - 23:00 2.00 DRILL P INT1 POH to shoe & monitor well. 2 stands at the top of the Schrader & at the Ugnu I Schrader interface had 50,000 & 55,000 Ibs. drag that required wiping once & they cleaned up well. The rest of TOH was slick. 23:00 - 23:30 0.50 DRILL P INT1 PJSM - Cutting drilling line. 23:30 - 00:00 0.50 DRILL P INT1 Cut drilling line. Trip tank on the hole to monitor for any potential losses. 12/1/2002 00:00 - 01 :00 1.00 DRILL P INT1 PJSM - cut & slip drilling line. 01 :00 - 03:00 2.00 DRILL P INT1 PJSM - Service top drive, drawworks, blocks, tighten & replace brake block nuts, adjust brakes & kick rollers. 03:00 - 05:30 2.50 DRILL N WAIT INT1 Wait for helicopter operations to resume for slinging 9 5/8" casing. Wait at shoe for possibility of RIH if slinging ops. are delayed. PJSM - Remove mud discharge manifold on mud pump # 2. 05:30 - 06:00 0.50 DRILL P INT1 Break circulation, pump dry job, BID top drive & lines. 00:00 - 05:00 - Lost 15 bbls. while circulating across the top of hole. 06:00 - 08:00 2.00 DRILL P INT1 PJSM - POH, UD porcupine reamer, std back HWDP. Monitor well. 08:00 - 10:30 2.50 DRILL P INT1 PJSM - UD BHA - clean & clear floor. Bit graded 3/4 10:30 - 11 :30 1.00 BOPSURP INT1 PJSM - Pull wear ring & install test plug. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Page 6 of22 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 . Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2002 11:30-13:00 1.50 BOPSUR P INT1 RIU to test BOP's. 13:00 - 17:30 4.50 BOPSUR P INT1 Test BOP's to 4800 I 250 psi for 5 / 5 min. Test annular preventer to 3500 psi. 17:30 - 18:00 0.50 BOPSUR P INT1 Pull test plug & install wear ring. 18:00 - 18:30 0.50 BOPSUR P INT1 BID lines & line up choke manifold. 18:30 - 19:00 0.50 DRILL P INT1 PJSM - M/U BHA. 19:00 - 21 :00 2.00 DRILL P INT1 M/U BHA # 4. 21 :00 - 21 :30 0.50 DRILL P INT1 Shallow test MWD & BID lines. 21 :30 - 23:00 1.50 DRILL N RREP INT1 PJSM - cia swivel packing. 23:00 - 00:00 1.00 DRILL N RREP INT1 PJSM - Service top drive, blocks, & crown. * Work on-going throughout the day removing & replacing discharge manifold on mud pump # 2 since 03:00. 12/2/2002 00:00 - 01 :30 1.50 DRILL N RREP INT1 Complete installation of new mud pump discharge manifold. Continue servicing top drive & replace swivel packing. 01 :30 - 03:30 2.00 DRILL P INT1 TIH to shoe. 03:30 - 04:30 1.00 DRILL P INT1 Fill pipe, break circulation & test mud pump wi new manifold, swivel packing, & rebuilt TIW valve. OK 04:30 - 06:00 1.50 DRILL P INT1 TIH to 6819' & wash through tight spot @ 3.5 BPM. RIH to 7400'. 06:00 - 07:00 1.00 DRILL P INT1 Wash & ream to 7739' from 7400'. 07:00 - 07:45 0.75 DRILL P INT1 Circulate 1 BU staging up to drilling rate. 07:45 - 11 :30 3.75 DRILL P INT1 Drill from 7738' to 8163' in 12 1/4" hole wi 9 5/8" motor w/1.15 deg. bent housing. No Drag, No Losses. Backreaming on connections smooth. 11 :30 - 12:00 0.50 DRILL N RREP INT1 Clean suction screen & replace valve spring in # 1 mud pump. 12:00 - 00:00 12.00 DRILL P INT1 Drill from 8163' to 9135' in 12 1/4" hole w/ 9 5/8" motor w/1 .15 deg. bent housing. Notes: 1) Packed off @ 8527' & lost partial returns momenta rilly. 17.0 ppg ECD spike. Was able to work pipe, regain full returns & continue drilling ahead. Resistivity log showed invasion at the point of the stabiliser. 2) ECD's in 9.7- 9.8 range. 3) Pumping hi-vis sweeps every 400'. 4) Survey @ 9012' md. Incl. 28.76, Az. 24.74 12/3/2002 00:00 - 09:30 9.50 DRILL P INT1 Drill & slide in 12 1/4" hole from 9135' to 9757'md wI 9 5/8" motor w/1.15 deg bent housing. Notes: 1) Pumping hi-vis sweeps every 400' 2) 2 % lubricants in mud system. (Torque trim & EP mudlube) 09:30 - 11 :30 2.00 DRILL P INT1 PJSM - Bleed in 12.7 ppg spike fluid off bottom as not to interfere wi recent slide. MW 10.1 ppg after bleed in. 11 :30 - 21 :00 9.50 DRILL P INT1 Drill & slide in 12 1/4" hole from 9757' to 10039 'md w/ 9 5/8" motor w/1.15 deg bent housing. 1) Sliding 40' - 60' on most stands. Printed: 2/3/2003 12:21 :21 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/3/2002 12/4/2002 12/5/2002 ) BP EXPLORATION Operations Summ·ary Report NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Frorn..To Hours Task Code NPT Phase 11 :30 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 00:00 - 12:00 12:00 - 14:30 14:30 -15:00 15:00 - 15:30 15:30 - 21 :00 21 :00 - 00:00 00:00 - 04:30 04:30 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:45 15:45 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 22:30 9.50 DRILL P 0.50 DRILL P 2.50 DRILL P 12.00 DRILL P 2.50 DRILL P 0.50 DRILL N 0.50 DRILL P 5.50 DRILL P 3.00 DRILL P 4.50 DRILL P 3.50 DRILL P 0.50 DRILL P 0.50 DRILL P 1.00 CASE P 2.00 CASE P 2.00 CASE N 0.50 CASE P 0.50 CASE P 0.75 CASE P 0.25 CASE P 0.50 CASE P 1.00 CASE P 5.00 CASE P RREP INT1 RREP INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 7 of22 Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Descr'iptionofOperations 2) Survey @ 9951' Inc134.35, Az 25.79 Service top drive. Drill ahead from 10039' to 10231' md. Top of HRZ 9839' md - 8795' TVD Top of Kuparuk 10066' md - 8982 TVD Max. gas @ 467 units Drill & slide in 12 1/4" hole from 10231' to TD @ 10743' wi 9 5/8" motor w/1.15 deg bent housing. Top of Miluveach @ 10670' md - 9467' TVD. Pump hi-his sweep prior to TD. Pump 50 bbl hi-vis weighted sweep & circulate 1.25 B/U. Hole cleaned up. Condition mud for casing. Stood back 3 stands while circulating. Troubleshoot & identify hydraulic cylinder seal out on top drive pipe handler. RIH from 10320' to 10735' & tag fill. (8') Monitor well- POH to 7956'. Tight spots wi 40,000 - 100,000 Ibs. drag in Kuparuk & HRZ from 10300' to 9656', No swabbing. Dry wipe tight spots. P/U weights did not decrease significantly on wiping, but running back in was never a problem wi SIO weights 195 - 210K. Consensus is we can get casing down. Trip from 9656' - 7956' was good wI avg drag 15K Pump out of hole due to tight hole & swab from 7956' - 6831' (Schrader) POH from 6831' to 6645' w/15K drag & no swab. Pump dry job. BID top drive & mud lines from pumping dry job, POH to shoe, monitor well, continue POH & standing back HWDP, & monitor well. OK Remaining TOH was good wI no drag or losses. PJSM - flush BHA & BID, UD BHA. Clean & clear floor - remove bails. PJSM - Pull wear ring & install test plug. PJSM - cia upper rams to 9 5/8". P/U casing equip't & bring to rig floor. Replace break-out ram on top drive. Continue repairs on top drive break-out ram. Test door seals on BOP's to 3500 psi. PJSM - Install mousehole & pull test plug. Install mousehole & pull test plug. PJSM - RIU Frank's fill up tool. PJSM - 'nstalllong bails. PJSM - RIU spiders, elevators, & casing tongs. M/U shoe track, engage Frank's tool & check floats. RIH wi 9-5/8" 471b. L-80 Mod. Butt. to 13-3/8 casing shoe. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Page 8 of 22 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From '- To Hours Task Code NPT Phase Descriptioh . of Operations 12/5/2002 22:30 - 23:00 0.50 CASE P INT1 Circulate casing volume at shoe @ 9 BPM 560 psi. No losses. 23:00 - 00:00 1.00 CASE P INT1 Continue RIH w/9 5/8" casing. 12/6/2002 00:00 - 08:30 8.50 CASE P INT1 Run 9 5/8" casing from 4400' to 10635 -- no problems. - Ran a total of 260 jts. 95/8" 471b. L-80 Mod. BTC. - Hole took 50 bbls while running casing. 08:30 - 09:00 0.50 CASE P INT1 M/U casing hangar, landing jt, & land casing wi 190K wt. in slips. Not necessary to wash down. 09:00 - 09:30 0.50 CEMT P INT1 LID Frank's fill up tool & M/U x-over & cement head. 09:30 - 13:30 4.00 CEMT P INT1 Establish circulation @ 1/2 BPM & stage up pumps in 1/2 BPM increments to 3 BPM; 1 BPM increments thereafter to 10 BPM. -ICP @ 1/2 BPM 1050 psi - FCP @ 10 BPM 730 psi Notes: 1) Circulated additional hour due to electricians changing out on Island. Electrician needs to be available for backfeeding G & I and Halliburton wI rig power in the event of power shutdown with Island solars. 2) Held cement job PJSM while circulating. 13:30 -14:00 0.50 CEMT P INT1 Pump 5 bls. water & pressure test cement lines to 4000 psi. 14:00 - 17:00 3.00 CEMT P INT1 Pump 50 bbls 11.0 ppg spacer & drop bottom plug. Pump 415 bbls (720 sx) type "G" lead cement followed by 116 bbls (565) sx type "G" tail & drop top plug. Wash up on top of plugs wi 25 bbls water from HOWCO. Switch over to rig pump & displace cement wi 751 bbls. 10.1 ppg mud. (Last 30 bbls switched over to sea water) Bumped plug wi 1700 psi @ 94.5% PE. Took pressure to 2200 psi & held for 2 min. Pressure held. Howco meter read 744 bbls. NO Losses noted during cement job. 17:00 - 18:00 1.00 CEMT P INT1 Check floats - OK. LID cement head & landing Jt. 18:00 - 18:30 0.50 WHSUR P INT1 Set packoff & test to 5000 psi for 10 min. 18:30 - 19:00 0.50 WHSUR P INT1 PJSM - Hook up kill line to 13 3/8" x 9 5/8" annulus. 19:00 - 21 :00 2.00 CEMT P INT1 Clean & clear rig floor of casing tools. cia bails. Begin pumping down 13 3/8" x 9 5/8" annulus w/1 0.1 ppg mud. Pumped 230 bbls @ 1/2 BPM. Pressure broke over @ 1400 psi, final pressure 910. Cleaning L pits. 21 :00 - 00:00 3.00 CASE N RREP INT1 PJSM, HACL on removing kelly hose. Disconnect hose from top drive & standpipe. 12/7/2002 00:00 - 00:30 0.50 CASE P INT1 PJSM on LID kelly hose. Complete flushing 13 3/8" x 9 5/8" annulus wi 230 bbls 10.1 ppg mud @ 1/2 BPM. Broke over @ 1400 psi - final pressure 910 psi 00:30 - 02:30 2.00 CASE N RREP INT1 LID kelly hose, string out new one on pad & PIU new hose. 02:30 - 03:00 0.50 CASE N RREP INT1 Lay new hose back down & tie back 7 stands HWDP back in fingers. 03:00 - 04:00 1.00 CASE P INT1 Remove 9 5/8" top rams & replace wI 7" x 4 1/2" variables. 04:00 - 04:30 0.50 CASE P INT1 RIU BOP testing equip't. Printed: 2/3/2003 12:21 :21 PM )) BPEXPLORATION Page90f22 Operations Sl.I mmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date· From.. To Hours Task Code NPT Phase Description of Operations 12/7/2002 04:30 - 09:30 5.00 CASE P INT1 Test BOP's to 250 14800 psi & hold 51 5. Test annular preventer to 3500 psi. 09:30 - 11 :30 2.00 CASE N RREP INT1 PJSM - Hang new kelly hose to stand pipe & attempt to connect at top drive. Will not fit - not enough tolerance for MIU on top drive. Will need to modify. 11 :30 - 12:00 0.50 CASE N RREP INT1 cia kelly hose softeners. 12:00 - 13:00 1.00 CASE N RREP INT1 PJSM - Remove x-over between "S" pipe on top drive & kelly hose for modification. (extension) 13:00 - 14:30 1.50 CASE P INT1 PJSM - Hammer up kelly hose on standpipe. Bring 8 1/2" BHA tools to rig floor. 14:30 - 15:00 0.50 CASE P INT1 Pull test plug & install wear ring. 15:00 - 16:30 1.50 CASE P INT1 MIU BHA up to CDR & RIH. Welder complete wi x-over extension modification. 16:30 - 18:00 1.50 CASE N RREP INT1 MIU x-over extension to "S" pipe & install kelly hose to x-over. 18:00 - 20:00 2.00 CASE N RREP INT1 Kelly hose too short; -6' shorter than previous hose & doesn't allow top drive to reach stops at bottom rails. Remove kelly hose. There is a new hose the proper length @ Nabors yard, but helicopters are unable to fly with current ceilings of 200'. Will mobilize new hose @ earliest opportunity. 20:00 - 22:30 2.50 CASE N RREP INT1 PJSM - Remove "S" pipe from top drive & tie kelly hose directly into goose neck. Plenty of clearance up & down, but bow in hose will not allow tripping pipe due to interference with latching elevators. 22:30 - 00:00 1.50 CASE N RREP INT1 Remove kelly hose & reinstall "S" pipe on top drive. Current plans are to hook up hose that was removed originally & cia during rig move. 12/8/2002 00:00 - 06:00 6.00 CASE N RREP INT1 PJSM - Remove kelly hose from standpipe & lower to ground. PJSM - P/U original kelly hose & MIU to standpipe. PJSM - M/U x-over & kelly hose to "S" pipe on top drive. 06:00 - 07:00 1.00 CASE N RREP INT1 PJSM - Test kelly hose to 4000 psi - BID lines. 07:00 - 07:30 0.50 CASE P INT1 PJSM for MIU BHA. 07:30 - 08:00 0.50 CASE P INT1 MIU BHA # 5. 08:00 - 09:00 1.00 CASE P INT1 Shallow test power drive & MWD @ 550 GPM 825 psi. - Control collar failure on power drive -- change out. 09:00 - 09:30 0.50 CASE N DFAL INT1 Retest power drive - OK 09:30 - 10:30 1.00 CASE N RREP INT1 Replace flow valve on pipe handler & re-sequence. 10:30 - 11 :00 0.50 CASE P INT1 Continue M/U BHA. 11 :00 - 12:00 1.00 CASE P INT1 RIH wi HWDP. 12:00 - 15:30 3.50 CASE P INT1 RIH to 10498' md. Tagged cement 70' above float collar. 15:30 - 16:00 0.50 CASE P INT1 Wash down from 10498' to 10589'. 16:00 - 16:30 0.50 CASE P INT1 Condition mud & circulate. 16:30 - 18:00 1.50 CASE N RREP INT1 PJSM - Adjust kelly hose, re-orient rotary hose x-over @ S pipe connection. 18:00 - 19:00 1.00 CASE P INT1 PJSM - pressure test 9 5/8" casing to 4100 psi for 30 min. - Review D2 & D5 drills. - PJSM for spike fluid addition. - Casing test satisfied retest on rotary hose. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Page 10 of 22 OperationsSummäry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations· 12/8/2002 19:00-19:15 0.25 CASE P INT1 BID kill line. 19:15 - 23:00 3.75 DRILL P INT1 Drill float collar & plugs and cleaned out rathole to 10743' md. - Added spike fluid while drilling shoe track while increasing 12.7 ppg MW. - Experienced packing off while drilling rathole wi 2 ECD spikes to 14.8 ppg EMW. 23:00 - 00:00 1.00 DRILL P INT1 Pulled into shoe and work pipe while cleaning up hole. - 505 GPM 120 RPM. 12/9/2002 00:00 - 01 :15 1.25 DRILL P INT1 Ream back through rat hole to 10743' @ 510 GPM, 80-100 RPM. Rat hole sticky & packing off. 01:15 - 02:45 1.50 DRILL P INT1 Drill 20' of new hole from 10743' - 10763'. 02:45 - 03:45 1.00 DRILL P LNR1 Pull back to shoe & perform FIT to 14.5 EMW wI 12. 7 ppg MW wi 900 psi. 03:45 - 04:30 0.75 DRILL P LNR1 Ream to 10763' & take ECD baselines as follows: o RPM - 13.68 60 RPM - 13.78 120 RPM - 13.84 04:30 - 14:00 9.50 DRILL P LNR1 Drill from 10763' to 10992' RaP's 15' - 40' FPH Discharge manifold on # 2 mud pump leaking @ flange where the newly replaced manifold makes up to the old. Decision made to POH for bit & pump repairs. 14:00 - 14:30 0.50 DRILL N DPRB LNR1 Monitor well & pull 4 stands to shoe. 14:30 - 15:00 0.50 DRILL N DPRB LNR1 Monitor well - pump dry job - BID lines. 15:00 - 18:30 3.50 DRILL N DPRB LNR1 POH to HWDP Repair pump manifold while POH. 18:30 - 20:00 1.50 DRILL N DPRB LNR1 Handle BHA. COR & flex lead collar were worn flat on side & bent. Required changing out. Suspected damage occurred while drilling rat hole. Bit had one nozzle plugged but looked good. 0 - 0 with 1 chipped tooth. 20:00 - 00:00 4.00 DRILL N DPRB LNR1 Handle BHA # 6. Items changed out: Bias unit & control collar CDR 8 1/2" stab. & x-over. Jars due to leaking. 12/10/2002 00:00 - 02:30 2.50 DRILL N DPRB LNR1 Replace control collar electronics & P/U new bias unit. - Shallow test - OK 02:30 - 03:00 0.50 DRILL N DPRB LNR1 Continue RIH wI BHA # 6. 03:00 - 04:00 1.00 DRILL N DPRB LNR1 UD Hydraulic jars & swap out wi new set due to leaking seal. 04:00 - 04:30 0.50 DRILL N DPRB LNR1 RIH wi HWDP to 991' 04:30 - 09:00 4.50 DRILL N DPRB LNR1 RIH to 10584' filling @ stds. 20, 65, 102. Note: Seemingly lost returns while RIH with stands 16 thru 20. * filled backside w/13 bbls and filled drill pipe w/15 bbls. Printed 2/3/2003 12:21 :21 PM )) BP EXPLORATION Page11 of 22 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1211 012002 04:30 - 09:00 4.50 DRILL N DPRB LNR1 * calc pipe fill was 32 bbls versus 28 bbls to fill hole and pipe. * determined float stuck open between stands 15 and 20. * circ drill string volume at 4 bpm to clear string of debris. * inc pump rate to 600 gpm and verify pressure to ensure jets not plug and MWD pulse -- everything is fine. 09:00 - 10:00 1.00 DRILL N DPRB LNR1 PJSM - Review procedures & obtain all work permits. 10:00 - 11 :00 1.00 DRILL N DPRB LNR1 Cut drilling line & adjust brakes. 11:00-13:30 2.50 DRILL N DPRB LNR1 Service top drive & drawworks. Grease crown, check bolts on # 2 mud pump manifold, check unions on kelly hose & "S" pipe. 13:30 - 19:00 5.50 DRILL N DPRB LNR1 RIH to 10744' and tagged up. Est circ & ream to 10992' md. Notes: -10743' md is the TD of 12-114" rathole. - Reamed 8-1/2" hole w/80 rpm, 500 gpm and 6K avg WOB. - Rotary stalls out & hole attempts to pack off if too aggressive. 19:00 - 00:00 5.00 DRILL P LNR1 Drill ahead in 8 1/2" hole wi RSS from 10992' to 11170' md. Notes: - Experienced some bit balling - treated wi 2 nut plug sweeps. - Rap 50' - 60' in Miluveach. - Calc ECD 13.5 and Measured ECD 13.8 ppg EMW. 12/11/2002 00:00 - 20:00 20.00 DRILL P LNR1 Drill w/RSS f/11860' -- 12297' md. Notes: - RSS responding well to downlinks. - PWD measuring ECD @ 0.4 ppg over calculated @ 11723' md; however, the measure ECD value reduced 0.1 ppg per stand until measured values matched calculated values of 13.75 @ 12106' md. The two values remained close for the next 3 connections to 12393' md. * highest ECD 13.9 ppg EMW. 20:00 - 20: 15 0.25 DRILL P LNR1 Service Top Drive. 20:15 - 00:00 3.75 DRILL P LNR1 Drill wlRSS f/12297' -- 12480' md. Notes: - PWD Measurements continued to match calculated values. - Some splintered shales across shakers -- bump mud weight to 12.9 ppg. - Pumped 25 bbl non-weighted sweep with 8 ppb nut plug and 10 ppb barafibre prior to penetrating SAG River -- no noticeable increase in cuttings when sweep at shaker. 12/12/2002 00:00 - 00:30 0.50 DRILL P LNR1 Drill ahead 8.5" hole from 12480' to Intermediate TD @12486' md. - Top Sag was @ 12449' md (TD- 37' into Sag) 00:30 - 01 :30 1.00 DRILL P LNR1 CBU 1.5 X's. Reciprocate. MW= 12.9 ppg. Shakers fairly clean. 01 :30 - 04:45 3.25 DRILL P LNR1 POOH. PU wt 350 K. SO wt 220 K Ibs. - Experience tight hole f/12204' to 12109' md. Wipe. - Backream from 12109' -12015' md (75 K-Ibs over). - Continue trip to shoe. At 10750' md (30 K over) through Miluveach. 04:45 - 05:00 0.25 DRILL P LNR1 Monitor well. 05:00 - 22:00 17.00 DRILL N DPRB LNR1 RIH to 10700'. Tight hole. Ream @ 80 spm/1500 psig and 80 rpm/15 K-Ibs torque through Miluveach. Tight hole continued through Kingak Reaming- tight hole all the way to bottom. Printed: 2/3/2003 12:21 :21 PM )) BP EXPLORATION Page 12 of 22 Operations Summary Rø·port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/12/2002 05:00 - 22:00 17.00 DRILL N DPRB LNR1 Pump viscous fiber sweep surface to surface. Sweep came back @ 8200 strokes. Lots of excess. Pump weighted sweep. Less excess on return. Shales look to be starting to run -- lower Kingak. 22:00 - 00:00 2.00 DRILL N LNR1 Condition MW to 13.1 ppg and working towards weight up to 13.3 ppg. - On bottoms up lots of shale returning. Reciprocating full stand pumping 570 gpm. 12/13/2002 00:00 - 05:30 5.50 DRILL N DPRB LNR1 'ncreae MW to 13.3 ppg while cleaning up well. - Pump rate 570 gpm wi 3225 psig. - Reciprocated full stand initially: * Found 3', 4', 8', 10',5' of fill in rat hole on successive reciprocations. * Hole attempted to pack off after 700 strokes pumped each time clean out fill. (Note: This was volume from TD to 9-5/8" shoe.) * Suspected Irritating Kingak. * Reduced reciprocation to 30' strokes -- fill at TD and packing problem disappeared. LESSON LEARNED. - Hole cleaned up progressively while weighting up from 12.9 ppg to 13.3 ppg: * Size of cuttings at shakers increased as mud weight increased -- denser fluid has more buoyancy. * Amount of cuttings decreased as mud wieght was increased -- hole cleaning up with volume pumped. - Achieved 13.3 ppg -- Immediately pumped high vis sweep: * Increased cutting amount at shakers with sweep around. * Shale returns became minimal after sweep around. Note: Lost swab on #2 pump. Double pump rate on #1 pump while repairing #2 -- no reduction in pump rate or AV. 05:30 - 07:30 2.00 DRILL P LNR1 Monitor well and POOH from 12486' md to 10658' md. - Hole condition much improved versus wiper trip: * Off bottom PU wt= 340 K Ibs & SO Wt= 220 K Ibs. * Average drag was 25K. * Seen one tight spot on first stand which required 425K to pull thru. * Seen both stabilizers pulling into the bottom of the 1 st 8-1/2" bit run depth @ 10992' md. -- Top stab pulled thru with 400K (75K overpull) and 2nd stab pulled thru with 425K (110 over pull). -- Drag increased from average 25K to average 50K while pulling bha thru the 1 st 8-1/2" bit run interval from 10743' to 10992' md. * Pulled through 12-1/4" rathole with no problems -- no overpull. 07:30 - 08:00 0.50 DRILL P LNR1 Monitor well. - Pump dry job. Blow down lines. - Drop 2.5" hollow steel rabbit on Std #102 when at 9-5/8" shoe. 08:00 - 11 :30 3.50 DRILL P LNR1 POOH to 1000' md. 11 :30 - 12:00 0.50 DRILL P LNR1 Monitor well. Printed: 2/3/2003 1221 :21 PM ) ) BP EXPLORATION Operations Summary Report . Page 130f 22 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From... To Hours Task Code NPT Phase Description of Operations 12/13/2002 11 :30 - 12:00 0.50 DRILL P LNR1 PJSM for LD of HWDP. 12:00 - 13:00 1.00 DRILL P LNR1 Lay Down 26 jts of 5" HWDP. 13:00 - 13:30 0.50 DRILL P LNR1 PJSM for LD of BHA#6. 13:30 - 15:30 2.00 DRILL P LNR1 LD BHA #6. - Bit graded: 1-0-BT-C-X-I-ER-TD. 15:30 - 16:00 0.50 DRILL P LNR1 Clear and clean rig floor. Pump squeeze on 13-3/8" x 9-518" OA as per plan: - Held PJSM in dog house with 2 operators from OPS, Howco cement crew, Day Tour Pusher, Motorman, Shakerhand, G&I supervisor and WSL. * Filled out NAD Fluid Transfer Permit. * Filled out NAD PJSM form. * Performed Hazard Analysis Checklist. - Pumped 5 bbls of water with Howco and test lines to 3000 psi. Pumped 65 bbls of water with Howco -- brokedown @ 1/4 bpm and 2000 psi. Increased rate throughout water ahead to 1-3/4 bpm and 3000 psi. - Pumped Job as follows: * 33 bbls of 15.7 ppg cement-- started @ 2 bpm at 3000 psi and finished @ 3bpm with 2950 psi. * 10 bbls of sea water @ 1 bpm and 540 psi. * 18 bbls of sea water @ 1/4 bpm and 250 psi. * Rig pumped 120 bbls of diesel @ 1 bpm (540 psi to 1120 psi). * Rig 40 bbls of sea water @ 3bpm -- final press 2580 psi. 16:00 - 16:30 0.50 CASE P LNR1 RU to run 7" liner. 16:30 - 17:00 0.50 CASE P LNR1 MU 6-1/4" BBL Reamer & 7" shoe track. - Bakerlock connections. - Check floats. Note: Continue downsqeeze on outer annulus. 17:00 - 22:30 5.50 CASE P LNR1 Run 49 joints total of 7",26#, L-80, Hydril 521 Drilling liner. - Jts 48 & 49 centrailized. Note: Completed downsqueeze on outer annulus. 22:30 - 23:00 0.50 CASE P LNR1 MU 7" Flex Lock II Hanger & ZXP liner top Assembly wI HRD running tool. 'nstallliner wiper plug and swivel. 23:00 - 23:30 0.50 CASE P LNR1 Inspect assembly and Mix and pour pawl mix. 23:30 - 00:00 0.50 CASE P LNR1 Wait 1/2 hr for mix to set. Prepare to circulate liner volume. 12/14/2002 00:00 - 01:15 1.25 CASE P LNR1 PU stand #1 and circulate line vol. BID lines. - PU WT = 115 K & SOW = 110 K Ibs 01 :15 - 07:00 5.75 CASE P LNR1 RIH with 7" liner on 5" DP. - Fill pipe on every 10 stands. - Limit speed to 100 fpm for surge. 07:00 - 09:00 2.00 CASE P LNR1 Circulate string volume (225 bbls) and take parameters: - PU Wt = 285K1 SOW= 210 KI ROT Wt= 245 K Ibs. - Torque = 10.5 K -Ibs w/15 rpm. 09:00 - 09:30 0.50 CASE P LNR1 RIH to 10775' md. 09:30 - 15:00 5.50 CASE P LNR1 Wash and ream f/1 0775' to 11065' md. - The first 8-1/2" (bent) BHA run was from TD of 12-1/4" @ 10743' md to 10992' md. Printed 2/3/2003 12:21 :21 PM ) ') BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From~To Hours Task Code NPT Phase Description of Operations 12/14/2002 09:30 - 15:00 5.50 CASE P LNR1 - Ran into 10743' md with no problem; however, required rotation and pumps immediately thereafter @ 10775' md. - 30-40 rpm wI 10-15 K-Ibs torque. WOB= 2-4 K Ibs. Pump rate 3 bpm. 15:00 - 16:00 1.00 CASE P LNR1 RIH wI 7" liner from 11065' md to 12281' md. - Hole in excellent shape other than stacked up on ledge @ 11558' md -- rotated past ledge with no pumps with 5 to 15K WOB. - Stacked up with 50K @ 11708' md -- bounced thru with 65K. 16:00 - 18:00 2.00 CASE P LNR1 Stacked up @ 12281' md. - Wash and ream from 12281' to 12307' md. * Packing off and stalling rotary from 12281' md to 12300' md. * No packing off while drilling reaming f/12300 to 12305' md. ** Reamed this section with 3 bpm and 30 rpm with 12K to 15K ft-Ibs torque and 2-3K WOB. ** Broke thru at 12305' md -- torque up stalled out and packed off. Reamed thru 12300' to 12307' md and broke thru. 18:00 - 18:30 0.50 CASE P LNR1 RIH from 12307' to 12470' md. 18' below top of Sag River fm @ 12452' md. \ - Hole was slick -- did not see Sag Kingak interface. - Did not tag fill (16' of rathole below shoe). 18:30 - 19:00 0.50 CASE P LNR1 MU 5' pup jt, TIW valve, and cementing head and manifold. 19:00 - 20:30 1.50 CASE P LNR1 Establish circulation. - Circulation staged up to 5 bpm wI 700 psig. When rate was increased to 5.5 bpm started experiencing packoff. Decision made to keep rate at 5 bpm. -No reciprocation and no rotation. Note: Pre-job safety meeting for cement job. 20:30 - 21 :00 0.50 CASE P LNR1 Pressure test and drop 1-3/4" ball. - Pump onto seat of Type 2 Landing collar. 21 :00 - 21 :30 0.50 CASE P LNR1 Pressure up to 2500 psig to set Flex-lock hanger. - Slack-off to 140 K Ibs. Pressure up to 3300 psig to release HRD running tool. - Bleed off pressure. PU 3' and see that HRD is released (275 K Ibs). - SIO to 185 K Ibs and apply right hand torque to align torque fingers. - SIO to 140 K Ibs. Pressure up to 4200 psig and blowout ball seat. - Bleed off pressure immediately to try and prevent packoff. 21 :30 - 22:00 0.50 CASE P LNR1 Estabished circulation. - Packed off briefly. Pressure up to 1000 psig- slowly lost pressure and went through staged circulation sequence again. - Final circulation rate 5 bpm wi 780 psig. 22:00 - 22:45 0.75 CEMT P LNR1 Cement as per plan: -Break circulation wi 13.2 ppg Alpha Spacer. Pump 5 bbls. SI and PT Halco lines to 4800 psig. - Pump remaining 30 bbls Alpha Spacer at 5 bpm. - Mix and pump 96 bbls of 15.9 ppg tail cement (330 sxs) @ 4.5 bpm wi 350 psig. 22:45 - 00:00 1.25 CEMT P LNR1 Drop Wipe Dart and Displace cement wi 13.3 ppg mud. - Catch cement at 274 strokes. Displace cement at 5 bpm. Printed: 2/3/2003 12:21 :21 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION Page 15 of 22 Operations Summary Report NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 From - To Hours Task Code N PT Phase LNR1 12/14/2002 22:45 - 00:00 12/15/2002 00:00 - 00: 15 00:15-01:30 01 :30 - 03:00 03:00 - 05:30 05:30 - 06:00 06:00 - 10:30 10:30 - 12:00 Descri ption' of Operations 1.25 CEMT P - Slow rate to 3.5 bpm as cement around shoe. - Latch up liner wiper plug at 2193 strokes. Experience pack off @ 2294 strokes (190 bbls Halco meter). Slow rate- pack off cleaned up and slowly increased rate to 4.0 bpm wi 660 psig. Packoff occured 200 strokes after shear wiper plug with 1100 psi which was also the calculated strokes for cement to the liner hanger. - Bump plugs @ 3084 strokes - 258 bbls on HALCO meter to 1200 psig. Set liner ZXP Liner Top Packer. Pull up to tool joint. Circulate out excess cement. - Approximately 10 bbls cement returned to surface. Cement carried quite a bit of smaller, ground-up cuttings from earlier reaming. This all due to low annular velocities in 5" DP x 9-5/8" and the low pump rates while reaming and cleanup for liner cementing. PJSM for LD of cement head. LD the same. PJSM for Displacing well to seawater. Pump SW displacement as per plan: 1) Pump 200 bbls sea water 2) Followed by 70 bbls hi-vis spacer 3) Followed with 760 bbls sea water - No Rotation or Reciprocation due to HRD running tool. - Average displacement rate 10 bpm. Max rate 12 bpm. - Final NTU of 310. Monitor well - neg test. POOH wi HRD Liner running tool. PJSM. - Service break and LD HRD liner running tool. * Upon inspection of running tool, it was noted that: ** the junk cover plate had been moved from it's position on the pipe body of the running tool -- there were marks left on the pipe from the set screws as evidence that the junk cover plate had moved down the tool. ** The pins on the HRD rotating mandrel had sheared. Note: Conclude that there was fill on top of the running tool when it was pulled out of the linerlhangerlpacker assy. Although there was only -25K overpull at surface, the pressure held on the pipe while pulling the seals out of the linerlhanger packer assy was increased from 1000 psi to 2500 psi on this job. This added drill pipe pressure provided a push force of -75K from below the liner running tool. Without this extra 1500 psi pushing from below, the PU Wt pulling out of the liner would have been -45K greater. LESSON LEARNED: If at the tensile limit of the drill pipe when attempting to pull off the liner, increase the drill pipe pressure to the lesser of the pump liner rating or 80% of burst of the of the 7" liner pipe -- this contingency requires: 1) the plug is bumped. 2) pumps are fitted with 5-112" liners even though the hole section was drilled with 6" liners. 3) surface lines are tested to this pressure prior to pumping cement. 0.25 CEMT P 1.25 CEMT P LNR1 LNR1 1.50 CEMT P 2.50 CEMT P LNR1 LNR1 0.50 CEMT P 4.50 CEMT P 1.50 CEMT P LNR1 LNR1 LNR1 Printed: 2/3/2003 1221 :21 PM ) ) BP EXPLORATION· Operéltion$SummaryReport Page,16 of 22 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2002 10:30 - 12:00 1.50 CEMT P LNR1 - PU cement head. Service break and LD. 12:00 - 14:00 2.00 CEMT P LNR1 PJSM for Pressure Test 9-5/8" x 7". - RU. - Pressure test to 4800 psig wI Sea Water. Record test for 30 mins. 14:00 - 15:00 1.00 TA P SURE Service rig Top Drive and Drawworks. 15:00 - 17:00 2.00 TA P SURE RIH wi 30 stds of DP for FZ Protect for suspension. 17:00 - 20:30 3.50 TA P SURE PJSM. - RU and reverse circulate 125 bbls of diesel into DP x 9-5/8" annulus at 1 bpm. Follow with 10 bbls of sea water for flush. - Line up to U-tube diesel. 20:30 - 22:30 2.00 TA P SURE U-tube diesel FZ Protect. 22:30 - 23:30 1.00 TA P SURE POOH wI 5" DP. 23:30 - 00:00 0.50 TA P SURE Drain U-tube lines. 12/16/2002 00:00 - 01 :30 1.50 T A P SURE Change out drilling sweep for production sweep. Pull wear ring. 01 :30 - 02:30 1.00 TA P SURE Rig up manifold on uppper annulus wi cellar pump to trip tank #1. Fill well with Sea water. 02:30 - 04:00 1.50 TA P SURE PJSM. MU tubing hanger wi TWC. Land wi test joint. RILDS. - Test seals to 5000 psig for 10 mins. 04:00 - 05:30 1.50 TA P SURE LD Test Jt. - Pressure Test TWC to 4200 psig for 5 mins. - Blow down lines and rig down test equipment. 05:30 - 07:00 1.50 TA P SURE Pull mouselhole, iron roughneck track, turnbuckles, and Koomey lines. 07:00 - 10:30 3.50 TA P SURE ND BOP's. 10:30 - 12:00 1 .50 T A P SURE ND Tree from NS21. 12:00 - 14:00 2.00 TA P SURE NU Tree on NS22. 14:00 - 15:00 1.00 TA P SURE Clean up cellar-pick up tools. 15:00 - 16:30 1.50 TA P SURE Prepare to move the rig. - OPS bleeding down annulus on NS27 to common line pressure. 16:30 - 17:00 0.50 TA P SURE Wait for OPS shift change to conduct PJSM for moving rig. RELEASE RIG FROM NS22 AT 1700 hrs. 1/16/2003 20:30 - 21 :00 0.50 MOB P SURE Prepare rig for move from NS18 to NS22. 21 :00 - 22:00 1.00 MOB P SURE PJSM for rig move. Obtain permit. Discuss SI timing of NS24 with Operator. Function moving system 22:00 - 00:00 2.00 MOB P SURE Begin rig move from NS18 to NS22. - At midnight 12' to go. 1/17/2003 00:00 - 01 :00 1.00 MOB P SURE Continue rig move from NS18 to NS22. - Spot up and level rig. ««« ACCEPT RIG AT 0100 HRS ON 1/17/2003 »»» 01 :00 - 04:00 3.00 RIGU P SURE Berm rig, close in cellar, secure stairs, clean up area around NS18. Electrician put rig and G & I back on highline. Assigned NS24 as ESD in cellar. ESD test. 04:00 - 05:30 1.50 WHSUR P SURE ND tree and secure on tree-stand in cellar. Install drilling sweep. I Printed: 2/3/2003 12:21 :21 PM ) ) BPEXPLORATION Page 17 öf22 Operations ·,Summary Report Drill 20' of new Sag River formation. Circulate MW in = MW out= 9.1 ppg FIT to 11.5 ppg EMW. Well control Discussion. - LCM pill mixed and ready - Forlift driver has salt pre-staged for brine making. - Well control board has been updated. Well control Drill. PROD1 Drill ahead 6-1/8" production hole and TD @ 12886' md/11149' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task 1/17/2003 05:30 - 09:30 4.00 BOPSUR P SURE 09:30 - 10:00 0.50 BOPSUR P SURE 10:00 - 11 :00 1.00 BOPSURP SURE 11 :00 - 19:00 8.00 BOPSUR P SURE 19:00 - 19:30 0.50 DRILL P SURE 19:30 - 22:00 2.50 DRILL P SURE 22:00 - 23:00 1.00 DRILL P SURE 23:00 - 00:00 1.00 DRILL P SURE 1/18/2003 3.00 DRILL P SURE 00:00 - 03:00 03:00 - 04:30 1.50 DRILL P SURE 04:30 - 05:00 0.50 DRILL P SURE 05:00 - 05:30 0.50 DRILL P SURE 05:30 - 09:00 3.50 DRILL P SURE 09:00 - 13:00 4.00 DRILL P SURE 13:00 - 14:00 1.00 DRILL P SURE 14:00 - 16:00 2.00 DRILL P SURE 16:00 - 18:00 2.00 DRILL P SURE 18:00 - 19:00 1.00 DRILL P SURE 19:00 - 21 :00 2.00 DRILL P SURE 21 :00 - 00:00 3.00 DRILL P SURE 1/19/2003 00:00 - 02:00 2.00 DRILL P SURE 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 04:30 1.00 DRILL P PROD1 04:30 - 21 :00 16.50 DRILL P Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Description of Operations PJSM for NU BOPE stack. NU BOP's. Install Roughneck track. - Reposition equipment on floor. Still waiting on VLE modification to be completed. RU and Prepare for BOP test. Pressure Test BOPE stack 250 psigl 4800 psig. - Test 4" and 5" equipement. ««« AOGCC Rep. John Crisp Witnessed Test »»» Run wear bushing. Clear and clean floor. VLE in operation. RIH wi 5" Open-ended DP taking steel displacement of diesel to Trip Tank #1. PJSM for displacement of wellbore from diesel to sea water. - SI bag. - Line choke through Gas-buster and back to Trip Tank #1. - PT line to G & I suction of disposal pump. - Displace out diesel with sea water charge pressure off the pipe rack. - Control TT level with choke. Circulate out diesel with Sea Water. -Used charge pressure off the pipe rack & 175 bbls total of sea water to displace out the 125 bbls diesel left on suspension. - Reverse circulate 40 bbls sea water to clear the 5" DP. PJSM for POOH while monitoring well. - POH. Pressure Test Casing to 4700 psig wi HALCO for 30 mins. PJSM for MU of BHA#7 (6-1/8" bit). PU BHA #7. - Load source in ADN. - Shallow Test. RIH wI BHA #7 Service Top Drive RIH wi BHA #7 Slip and cut drilling line. Pump 100 bbls hi-vis Barazan spacer and chase with sea water. RIH wi BHA #7 into 7" liner. - Wash last stand down before Plugs and Landing Collar. Drill out plugs and landing collar. Drill out Shoe track and hard cement to old hole TO @ 12486' md. Printed: 2/3/2003 12:21 :21 PM ) ') BP EXPLORATION Ope ratio nsSulTI maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From -'- To Hours Task Code NPT Phase Description of Operations 1/19/2003 04:30 - 21 :00 16.50 DRILL P PROD1 tvd - Rap 35 to 80 fph wI final average Rap of 26.3 fph. - Drilling Parameters: Torque 16-17 K w/85 rpm and 0.25% EP mud lube & 1.25% Torque Trim in the mud system, 303 gpm total flow wi 1900 psi. WOB = 25K. - Final hole inclination 40.55 deg I azimuth: 20.94 deg. - Max gas 680 units in Ivishak - Top Shublick 12632' md/1 0953' tvd rkb - Top Ivishak 12730' md/11 028' tvd rkb. - MW dressed out to 9.3 ppg at TD for liner run and trip. 21 :00 - 22:30 1.50 DRILL P PROD1 CBU: - Pump 30 bbls hi-vis spacer. - Plan to place spacer in 9-5/8". Circulate 6800 strokes. 22:30 - 23:00 0.50 DRILL P PROD1 Monitor well. 23:00 - 00:00 1.00 DRILL P PROD1 Check trip to 7" shoe: - Hole in good condition. PU Wt off 325 K Ibs. - Continue to pull to 7" liner top to open PBL sub. 1/20/2003 00:00 - 01 :30 1.50 DRILL P PROD1 POOH placing PBL sub just below 7" liner top at 10500'. 01 :30 - 05:30 4.00 DRILL P PROD1 Drop ball and open PBL sub. - Pump 70 bbls viscosified LCM sweep and chase with 9.3 ppg Mud at 17 bpm. - Reciprocated pipe wlo rotation. - Shakers full of Ivishak formation sand through out entire circulation. - Sweep brought quit a bit of excess, however returns did not cleanup. - Pump 2nd 70 bbls hi-vis sweep surface to surface. - Shakers finally clean after recovering 2nd sweep. 05:30 - 06:00 0.50 DRILL P PROD1 Drop steel ball for closing PBL. - Pump onto seat at 17 spm (26 mins to seat). 06:00 - 07:00 1.00 DRILL P PROD1 RIH to 7" shoe wi BHA #7. 07:00 - 07:30 0.50 DRILL P PROD1 Monitor well at shoe. 07:30 - 08:00 0.50 DRILL P PROD1 Pump dry job and drop 2.5" rabbit. 08:00 - 09:00 1.00 DRILL P PROD1 POOH. - Pulling wet string. 09:00 - 09:30 0.50 DRILL P PROD1 Pump 2nd dry job. 09:30 - 14:30 5.00 DRILL P PROD1 POOH to 4" DP. Change elevators to 4". 14:30 - 19:30 5.00 DRILL P PROD1 POOH wi 4". PJSM for handling source. - LD BHA#7 - Bit was used hard and 1/4" out of gauge. Grade: 3-6-WO-A-E-4-RG- TD 19:30 - 20:00 0.50 DRILL P PROD1 Clear and clean floor. 20:00 - 22:30 2.50 DRILL P PROD1 Service top drive. Grease crown, tugger, and man-rider sheaves. Note: Tour Pusher conducted pre-job and HACL for crown work- no procedure currently in place for crown service. 22:30 - 23:00 0.50 CASE P PROD1 PJSM for rigging up to run production liner. 23:00 - 00:00 1.00 CASE P PROD1 Continue to rig up compensator, etc for torque turning 4.5" liner. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2003 00:00 - 00:30 0.50 CASE P CaMP Rig up to run 4 1/2" 12.6# 13Cr Vam Ace solid liner 00:30 - 02:00 1.50 CASE P CaMP PJSM; Make up float equipment, check float Run 4-1/2" 12.6# 13 Cr Vam Ace liner -13 joints 02:00 - 04:00 2.00 CASE P CaMP PJSM Change out equipment to 2-7/8 for inner string 04:00 - 06:30 2.50 CASE P CaMP PJSM Run 2-7/8" inner string - 16 joints + pups MU hanger Fill liner with 10.0 ppg viscosified brine (2-7/8" x 4-112") Fill packer with Pal mix 06:30 - 07:00 0.50 CASE P CaMP Change out equipment to 4" - clear floor 07:00 - 07:30 0.50 CASE P CaMP Circulate liner volume. 07:30 - 17:00 9.50 CASE P CaMP RIH with liner and inner string. Fill every 10 stands 17:00 - 18:00 1.00 CASE P CaMP Circulate one string volume (2400 strokes). 18:00 - 19:00 1.00 CASE P CaMP Run liner into open hole and tag TD at 12,886' MD PU - 310,000 Ibs SO - 235,000 Ibs ROT - 10,000 ftlbs 19:00 - 19:30 0.50 CEMT P CaMP Rig up cement line 19:30 - 21 :30 2.00 CEMT P CaMP Establish circulation, slowly, up to 7 bpm. No losses. 21 :30 - 22:30 1.00 CEMT P CaMP Pump cement as per program: 25 bbls 10.3 ppg Alpha spacer 27 bbls 15.9 ppg Class G Cement No Losses; Bumped the plug at 2355 strokes (97% eft) with 3000 psi 22:30 - 23:30 1.00 CEMT P CaMP Set liner hanger at 3000 psi, released from HRD at 4000 psi. Set liner top packer and confirmed with rotation. 23:30 - 00:00 0.50 CEMT P CaMP Circulate out cement at 14 - 16 BPM. 1/22/2003 00:00 - 01 :00 1.00 CEMT P CaMP Circulate cement out of the hole at 8 - 10 bpm. Returned 25 bbls of Alpha spacer and 10 bbls of cement at bottoms up at 6800 strokes. 01 :00 - 01 :30 0.50 CEMT P CaMP PJSM; Shut the Hydril and pressure test the liner top to 1500 psi - All ok. 01 :30 - 04:00 2.50 CEMT P CaMP Circulate in 50 bbls of caustic wash spacer, 50 bbls of dirt magnet spacer, followed by 50 bbls of N-vis seawater sweep. Circulation rates ranged from 7 - 8 bpm at the beginning of the circulation to 11- 12 bpm after surface-to-surface strokes were obtained. The well was circulated approximately 14000 strokes (9100 strokes being surface-to-surface) until the seawater registered 61 NTU's. 04:00 - 04:30 0.50 CEMT P CaMP Shut down and monitor for 30 minutes for flow. No flow detected. Negative pressure test passed - all ok. 04:30 - 05:30 1.00 CEMT P CaMP Lay down the cement head, drill pipe single, valves, and hoses. Blow down topdrive and mudline. 05:30 - 12:00 6.50 CEMT P CaMP POOH with 5" x 4" drill pipe. 12:00 - 15:00 3.00 CEMT P CaMP Continue to POOH with 2-7/8" inner string. LD same. 15:00 - 16:30 1.50 CEMT P CaMP Lay down Baker running tool. Break down cement head. 16:30 -17:00 0.50 CEMT P CaMP Rig up to test the liner lap to 3750 psi. 17:00 - 18:00 1.00 CEMT P CaMP Hold the liner lap test to 3750 psi for 30 minutes. Test OK. 18:00 - 00:00 6.00 CEMT N WAIT CaMP Wireline unit not available. Rig maintenance performed. 1. Monthly electrical service performed on top drive. 2. PJSM; Pull the rotary table to repair motor. Printed: 2/3/2003 1221 :21 PM ) \) BP EXPLORATION OPE!rations Summaryl~epört Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Dåte From~ To Hours Task Code NPT Phase Description of Operations . 1/22/2003 18:00 - 00:00 6.00 CEMT N WAIT CaMP 1/23/2003 00:00 - 02:30 2.50 CEMT N WAIT CaMP PJSM; Continue work on the Rotary table motor. Set the rotary table in place. Install chain, set floor plates. Clear floor 02:30 - 05:00 2.50 CEMT N WAIT CaMP Replace the valve and hoses on the iron roughneck. Service same. 05:00 - 12:00 7.00 CEMT N WAIT CaMP Service pipe shed elevator. Replace motor on ventilation fan in boiler room. Perform zonal derrick inspectioin. Clean rig. 12:00 - 17:00 5.00 CEMT N WAIT CaMP Zonal derrick inspection continued. PUll top oft degasser and replace gasket. 17:00 - 18:00 1.00 CEMT N WAIT CaMP Service top drive, crown and drawworks 18:00 - 22:00 4.00 CEMT N WAIT CaMP Clean rig floor; Service derrick climber; Blow down mud line; replace bearing oin mac air heater. 22:00 - 00:00 2.00 CLEAN P CaMP PJSM; RU Wireline for #1 run for gamma ray; casing collar locator; and junk basket with a 3.75" gauge. RIH at 23:30 hrs. 1/24/2003 00:00 - 04:00 4.00 CLEAN P CaMP RIH to 10,463' WLM, hung up. Cannot pass through. Hanging up on 7" liner top (10,458' MD). Tried repeated attempts to pass through liner top with no luck. Decision was make to POOH and change assemblies. The current assembly was a typical junklboot basket with a 3.75" gauge ring at the bottom. Upon POOH, the base of the gauge ring had considerable markings on it where it was hanging up on the liner top. 04:00 - 11 :00 7.00 CLEAN P CaMP Change out wireline assembly to a centralized 3.625" gauge ring (slickline tool) with a sample catcher below. RIH to tag TD at 12,860' WLM = 12848' MD. A large overpull was required when pulling up oft bottom. -32' of fill. Bottom perforations to be @ 12806'. Hole good to run tubing. 11 :00 - 12:00 1.00 CLEAN P CaMP RD wireline 12:00 - 12:30 0.50 CASE P CaMP PJSM; Pull wear ring 12:30 - 14:00 1.50 CASE P CaMP PJSM; Install Vetco Gray junk basket; Rig up flushing tool and flush BOP's. Rig down flushing tool and pull junk basket. 14:00 -15:00 1.00 CASE P CaMP Blow down all lines. Lay down flushing tool and clear rig floor. 15:00 - 15:15 0.25 RUNCOI'vP CaMP PJSM on rigging up tubing running tools. 15:15-15:45 0.50 RUNCOI'vP CaMP Rig up tubing tongs, etc. 15:45 - 16:15 0.50 RUNCOI'vP CaMP PJSM on rigging up fiber optic cable 16:15 - 18:00 1.75 RUNCOI'vP CaMP Bring fiber optic tools, etc. to the rig floor 18:00 - 18:30 0.50 RUNCOI'vP CaMP PJSM; Hang sheave at monkey board. 18:30 - 19:00 0.50 RUNCOI'vP CaMP Attempt to make up cross over to the hanger. Could not as the heads for the tongs were wrong. Will do this after running tubing when correct heads arrive (exptected to arrive 1/25/03) 19:00 - 19:45 0.75 RUNCOI'vP CaMP PJSM on running 3-1/2" 13Cr-80 9.2ppf tubing (384 joints, 1 TR-SSSV, 1 glm (dummy), 1 glm (RP valve), 1 Cidra mandrel, 2 'X' nipples, 1 packer, 1 'XN' nipple, and a self aligning WLEG using API modified thread compound. 19:45 - 00:00 4.25 RUNCOI'vP CaMP Run the completion assembly. At midnight in hole with Baker Locked tailpipe assembly and 32 joints of 3 1/2" tubing. None rejected, none damaged. 1/25/2003 00:00 - 12:00 12.00 RUNCOI'vP CaMP Run 3-1/2" vam ace tubing with Cidra cable. Reject one joint (two total for job). 12:00-12:30 0.50 RUNCOI'vP CaMP Received the proper heads for the tongs. Make up cross over to hanger. 12:30 - 22:15 9.75 RUNCOI'vP CaMP Continue running in with the 3-1/2" tuibing. Had to break out Printed: 2/3/2003 12:21 :21 PM ), ) BP EXPLORATION. Operations Summary Report< Page 21 of 22 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Spud Date: 11/21/2002 End: 1/27/2003 Date From ;.To Hours Task Code NPT Phase Description of Operations 1/25/2003 12:30-22:15 9.75 RUNCOrvP CaMP one joint; make up all ok. 22: 15 - 22:30 0.25 RUNCOrvP CaMP PJSM on rigging up of the control line for the SSSV. 22:30 - 23:15 0.75 RUNCOrvP CaMP Rig up the control line to the SSSV. Test to 6,000 psi for 15 minutes. All ok. 23:15 - 00:00 0.75 RUNCOrvP CaMP Continue running in hole with tubing to joint #360 of 384. 1/26/2003 00:00 - 02:15 2.25 RUNCOrvP CaMP Continue to run the 3-1/2" Vame Ace Chrome completion string. 02:15 - 03:00 0.75 RUNCOrvP CaMP Install the head pin assembly. Break circulation above anticipated top of liner. Establish circulation at 3 BPM (SPP at 220 psi) and slowly RIH, monitoring pressure. Did not see any positive pressure indication on the pressure gauge or on the Cidra system. Did see a slight bobble approximately 10 feet before stacking up. Repeat twice. 03:00 - 05:00 2.00 RUNCOrvP CaMP Lay down 3 joints (#387, 386, 385) for space out. Used three pups, 9.83' , 9.82', and 2.13'. Make up pups, hanger, and landing joint. 05:00 - 07:30 2.50 RUNCOrvP CaMP Terminate the SSSV control line and splice the Cidra line. 07:30 - 08:00 0.50 RUNCOrvP CaMP Land the hanger and RILDS. 08:00 - 08:30 0.50 RUNCOrvP CaMP Change out the drilling sweep for the production sweep at the wellhead. Move the kill line to the annulus. 08:30 - 09:00 0.50 RUNCOrvP CaMP Rig down the single joint elevator and compensator. 09:00 - 10:00 1.00 RUNCOrvP CaMP Rig down the Cidra sheave and cable from the derrick 10:00 - 12:00 2.00 RUNCOrvP CaMP Rig up to the landing joint. Pump down the annulus to verify fluid path. Drop the ball and rod to set the packer. Pressure up to 4200 psi (packer setting pressure at 2500 psi). 12:00 - 12:45 0.75 RUNCOrvP CaMP Test the 3 1/2" tubing to 4200 psi for 30 minutes. Test OK. 12:45 - 13:00 0.25 RUNCOrvP CaMP Blow down the mud line. 13:00 -14:00 1.00 RUNCOrvP CaMP Bleed down the tubing to 3000 psi. Pressure up the annulus to 4200 psi. Test the 3 1/2" x 9 5/8" annulus to 4200 psi for 30 minutes. Test OK. 14:00 - 14:15 0.25 RUNCOrvP CaMP Bleed down both tubing and annulus. Pressure up annulus to 2500 psi to shear RP in bottom GLM. Sheared @ 2500 psi & continue pumping for 5 minutes @ 3 BPM 14:15 - 15:00 0.75 RUNCOrvP CaMP Close SSSV and test from below to 1000 psi for 30 minutes. 15:00 - 15:30 0.50 RUNCOrvP CaMP PJSM on freeze protection of 95/8" x 3 1/2" annulus. 15:30 - 16:00 0.50 RUNCOrvP CaMP Mix corrosion inhibitor. 16:00 - 16:15 0.25 RUNCOrvP COMP Pump corrosion inhibitor at 3 BPM at 780 psi. 16:15 - 21:30 5.25 RUNCOrvP COMP Pump diesel at 1 BPM. By the rig stroke counter, 3654 strokes (309 bbls) were pumped. 21 :30 - 21 :45 0.25 RUNCOrvP CaMP Pump 10 bbls of seawater at 3 BPM 21:45 - 22:15 0.50 RUNCOIVP CaMP U-tube diesel at apprximately 2 BPM. Halliburton meter showed 40 bbls of U-tube inside tubing. Calculated 4000' of 3 1/2" tubing capacity to be approximately 35 bbls. U-tube all ok. 22:15 - 22:30 0.25 RUNCOr\f> CaMP Blow down lines 22:30 - 23:00 0.50 RUNCOIVP CaMP Rig down manifold from landing joint. 23:00 - 23:45 0.75 RUNCOIVP CaMP Lay down landing joint. 23:45 - 00:00 0.25 RUNCOIVP CaMP Set lWC 1/27/2003 00:00 - 00:30 0.50 RUNCOIVP CaMP Test lWC to 1000 psi for 10 minutes from below. Blow down lines. 00:30 - 05:00 4.50 RUNCOIVP CaMP Pull the mousehole. Nipple down BOPE. 05:00 - 11 :30 6.50 RUNCOIVP CaMP Teminate the SSSV line. Clean up top of hanger. Splice the Cidra fiber optic line. 11 : 30 - 13: 15 1.75 RUNCOIVP CaMP Nipple up the production tree. Printed: 2/3/2003 12:21 :21 PM ) ) BP EXPLORATION Operations Sum.R1ary.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/27/2003 NS22 NS22 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E From.;. To Hours Task Code NPT Phase 13:15 - 14:00 0.75 RUNCOMP CaMP 14:00 - 14:30 0.50 RUNCOMP CaMP 14:30 - 15:00 0.50 RUN CaMP CaMP Start: 11/21/2002 Rig Release: 1/27/2003 Rig Number: 33E Page 22 of 22 Spud Date: 11/21/2002 End: 1/27/2003 Descri ption ot Qperations PJSM; Pressure test the tree and void area with diesel. Test to 5000 psi for 15 minutes. Dress out tree and pull the TWC valve. Pick up and clean Cellar area. Release rig from NS22 at 15:00 hrs. Printed: 2/3/2003 12:2121 PM bp NS22 Schlumbepgep Survey Report - Geodetic Report Date: 19-Jan-03 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 25.590° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS22 TVD Reference Datum: KB Well: NS22 TVD Reference Elevation: 56.510 ft relative to MSL Borehole: NS22 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWUAPI#: 500292312800 Magnetic Declination: +26.114° Survey Name I Date: NS221 January 19, 2003 Total Field Strength: 57548.986 nT Tort I AHD I DDII ERD ratio: 133.539° 16175.17 ft 15.979/0.554 Magnetic Dip: 80.950° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: December 20, 2002 .'"-' Location LatlLong: N 70.49132358, W 148.69331433 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 6031031.560 ftUS, E 659826.690 ftUS North Reference: True North Grid Convergence Angle: +1.23169393° Total Corr Mag North -> True North: +26.114° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6031031.56 659826.69 N 70.49132358 W 148.69331433 50.00 0.76 184.47 50.00 -0.31 -0.33 -0.03 1.52 6031031.23 659826.67 N 70.49132267 W 148.69331454 100.00 1.58 187.68 99.99 -1.27 -1.34 -0.14 1.64 6031030.21 659826.58 N 70.49131990 W 148.69331551 150.00 2.69 187.88 149.95 -3.05 -3.19 -0.40 2.22 6031028.36 659826.36 N 70.49131486 W 148.69331758 200.00 3.35 185.25 199.88 -5.54 -5.81 -0.69 1.35 6031025.74 659826.12 N 70.49130771 W 148.69331998 234.50 3.33 194.66 234.32 -7.46 -7.78 -1.04 1.59 6031023.76 659825.82 N 70.49130232 W 148.69332281 263.50 2.21 192.63 263.29 -8.84 -9.14 -1.37 3.88 6031022.39 659825.51 N 70.49129861 W 148.69332555 291.50 1.50 205.80 291.28 -9.73 -10.00 -1.65 2.94 6031021.53 659825.26 N 70.49129627 W 148.69332782 320.50 0.53 145.19 320.27 -10.18 -1 0.45 -1.74 4.56 6031021.08 659825.18 N 70.49129503 W 148.69332854~ 359.50 0.99 76.30 359.27 -10.05 -10.52 -1.31 2.41 6031021.02 659825.61 N 70.49129485 W 148.69332503 388.50 1.75 57.02 388.26 -9.51 -10.22 -0.69 3.03 6031021.33 659826.22 N 70.49129567 W 148.69332000 472.50 4.79 54.23 472.11 -5.34 -7.47 3.23 3.62 6031024.16 659830.08 N 70.49130318 W 148.69328794 566.00 6.68 45.67 565. 14 3.19 -1.39 10.29 2.21 6031030.40 659837.00 N 70.49131979 W 148.69323024 657.00 8.13 45.96 655.38 14.20 6.79 18.70 1.59 6031038.75 659845.24 N 70.49134212 'W 148.69316148 724.00 8.98 44.44 721.64 23.59 13.81 25.77 1.31 6031045.92 659852.15 N 70.49136131 W 148.69310371 837.00 11.21 39.81 832.88 42.58 28.55 38.98 2.10 6031060.94 659865.04 N 70.49140157 W 148.69299574 926.00 14.01 44.20 919.73 61.18 42.92 52.03 3.32 6031075.59 659877.78 N 70.49144083 W 148.69288904 1020.00 15.60 57.84 1010.63 82.66 57.81 70.67 4.06 6031090.87 659896.09 N 70.49148151 W 148.69273668 NS22 ASP Final Survey.xls Page 1 of 5 3/10/2003-12:39 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) n (") (ft) (ft) (ft) (ft) (" 11 OOft) (ftUS) (ftUS) 1113.00 17.70 54.67 1099.73 105.60 72.65 92.79 2.46 6031106.18 659917.89 N 70.49152203 W 148.69255584 1209.00 21.88 52.01 1190.04 134.39 92.10 118.81 4.45 6031126.19 659943.48 N 70.49157519 W 148.69234317 1302.00 23.99 50.13 1275.69 167. 11 114.89 146.98 2.40 6031149.58 659971.15 N 70.49163745 W 148.69211289 1397.00 25.47 49.17 1361.97 203.40 140.63 177.26 1.61 6031175.96 660000.87 N 70.49170775 W 148.69186536 1488.00 27.14 44.44 1443.55 240.98 168.25 206.60 2.94 6031204.20 660029.61 N 70.49178320 W 148.69162550 1583.71 27.79 39.79 1528.49 283.27 200.98 236.17 2.34 6031237.56 660058.46 N 70.49187262 W 148.69138379 1676.92 28.24 . 35.10 1610.78 326.09 235.72 262.76 2.41 6031272.86 660084.30 N 70.49196753 W 148.69116643 1767.22 27.83 31.97 1690.49 368.11 271 .09 286.20 1.69 6031308.72 660106.98 N 70.49206413 W 148.69097476 1861.09 28.02 26.83 1773.44 411.94 309.36 307.76 2.57 6031347.44 660127.71 N 70.49216868 W 148.69079853 1957.29 27.42 25.75 1858.60 456.68 349.47 327.58 0.81 6031387.97 660146.66 N 70.49227827 W 148.69063648 2050.94 27.40 26.64 1941 .74 499.79 388.15 346.61 0.44 6031427.05 660164.85 N 70.49238394 W 148.69048090 ~ 2143.21 27.33 22.46 2023.69 542.17 426.71 364.22 2.08 6031465.97 660181.63 N 70.49248927 W 148.69033690 2236.70 26.84 20.79 2106.93 584.63 466.28 379.91 0.97 6031505.86 660196.47 N 70.49259735 W 148.69020862 2329.71 25.84 21.93 2190.28 625.79 504.71 394.94 1.20 6031544.61 660210.66 N 70.49270235 W 148.69008579 2424.00 27.85 19.45 2274.41 668.20 544.54 409.95 2.44 6031584.75 660224.81 N 70.49281117 W 148.68996306 2519.45 29.11 20.04 2358.31 713.47 587.38 425.33 1.35 6031627.90 660239.26 N 70.49292819 W 148.68983731 2612.91 28.91 21.10 2440.04 758.62 629.81 441.25 0.59 6031670.67 660254.27 N 70.49304411 W 148.68970712 2707.10 29.24 22.15 2522.36 804.28 672.36 458.12 0.65 6031713.56 660270.22 N 70.49316034 W 148.68956919 2802.04 29.37 22.85 2605.15 850.69 715.29 475.91 0.39 6031756.87 660287.08 N 70.49327762 W 148.68942379 2899.39 27.55 21.37 2690.74 896.99 758.26 493.38 2.00 6031800.20 660303.62 N 70.49339500 W 148.68928090 2995.72 27.11 21.39 2776.31 941 .09 799.45 509.50 0.46 6031841.71 660318.86 N 70.49350750 W 148.68914907 3092.54 27.79 22.45 2862.23 985.63 840.85 526.17 0.86 6031883.46 660334.63 N 70.49362060 W 148.68901281 3188.01 26.16 19.60 2947.32 1028.79 881 .25 541 .73 2.18 6031924.18 660349.31 N 70.49373097 W 148.68888558 3283.49 24.86 16.76 3033.49 1069.56 920.29 554.58 1.87 6031963.49 660361.32 N 70.49383764 W 148.68878051 3378.92 25.79 17.53 3119.75 1109.94 959.30 566.62 1.03 6032002.75 660372.51 N 70.49394419 W 148.68868207 3474.58 25.69 17.76 3205.92 1151.08 998.89 579.21 0.15 6032042.59 660384.25 N 70.49405234 W 148.68857910~' 3568.22 25.33 18.47 3290.43 1191.07 1037.22 591.75 0.50 6032081.18 660395.96 N 70.49415705 W 148.68847658 3654.29 29.42 22.54 3366.85 1230.46 1074.22 605.69 5.22 6032118.48 660409.11 N 70.49425814 W 148.68836256 3764.19 29.88 23.11 3462.36 1284.77 1124.33 626.78 0.49 6032169.02 660429.11 N 70.49439503 W 148.68819009 3856.16 29.92 24.69 3542.09 1330.59 1166.24 645.35 0.86 6032211.32 660446.78 N 70.49450952 W 148.68803822 3951.04 29.62 23.62 3624.45 1377.68 1209.23 664.63 0.64 6032254.70 660465.13 N 70.49462694 W 148.68788058 4043.64 29.20 23.28 3705.11 1423.12 1250.94 682.73 0.49 6032296.80 660482.32 N 70.49474089 W 148.68773260 4137.42 29.29 23.53 3786.94 1468.91 1292.99 700.93 0.16 6032339.22 660499.61 N 70.49485575 W 148.68758377 4228.61 28.76 23.74 3866.68 1513.12 1333.52 718.66 0.59 6032380.12 660516.47 N 70.49496648 W 148.68743873 4322.20 28.65 24.44 3948.77 1558.06 1374.56 737.01 0.38 6032421.54 660533.93 N 70.49507858 W 148.68728869 NS22 ASP Final Survey.xls Page 2 of 5 3/10/2003-12:39 PM ~. Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S E/-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 4416.14 29.34 23.08 4030.93 1603.57 1416.23 755.35 1.02 6032463.60 660551.37 N 70.49519243 W 148.68713871 4509.64 29.11 24.07 4112.53 1649.19 1458.07 773.61 0.57 6032505.82 660568.72 N 70.49530672 W 148.68698942 4603.12 30.03 23.68 4193.84 1695.30 1500.26 792.28 1.01 6032548.39 660586.48 N 70.49542196 W 148.68683675 4698.87 30.99 22.58 4276.33 1743.86 1544.96 811.37 1.16 6032593.49 660604.60 N 70.49554408 W 148.68668064 4793.04 31.83 23.13 4356.70 1792.88 1590.18 830.43 0.94 6032639.11 660622.69 N 70.49566761 W 148.68652474 4884.33 30.81 24.46 4434.68 1840.31 1633.60 849.57 1.35 6032682.93 660640.89 N 70.49578622 W 148.68636823 4979.66 29.55 24.68 4517.09 1888.23 1677.19 869.49 1.33 6032726.93 660659.87 N 70.49590528 W 148.68620528 5072.97 29.42 23.99 4598.32 1934.14 1719.03 888.42 0.39 6032769.17 660677.89 N 70.49601959 W 148.68605050 5166.47 29.11 24.13 4679.88 1979.83 1760.77 907.05 0.34 6032811.29 660695.62 N 70.49613361 W 148.68589810 5260.83 28.07 25.71 4762.74 2024.98 1801.72 926.07 1.36 6032852.64 660713.75 N 70.49624547 W 148.68574259__/ 5356.72 27.88 25.88 4847.42 2069.96 1842.22 945.64 0.21 6032893.54 660732.45 N 70.49635610 W 148.68558251 5451.22 27.94 26.01 4930.93 2114.19 1882.00 964.99 0.09 6032933.72 660750.94 N 70.49646476 W 148.68542424 5542.80 28.23 26.04 5011.73 2157.31 1920.74 983.91 0.32 6032972.86 660769.02 N 70.49657059 W 148.68526953 5636.56 28.04 26.51 5094.41 2201.52 1960.38 1003.48 0.31 6033012.91 660787.73 N 70.49667889 W 148.68510946 5733.46 28.17 26.44 5179.88 2247.16 2001.24 1023.83 0.14 6033054.20 660807.19 N 70.49679051 W 148.68494302 5823.78 28.60 26.58 5259.34 2290.09 2039.67 1043.00 0.48 6033093.02 660825.53 N 70.49689546 W 148.68478627 5918.17 28.34 26.94 5342.32 2335.08 2079.84 1063.26 0.33 6033133.62 660844.92 N 70.49700521 W 148.68462057 6014.32 28.27 26.61 5426.97 2380.66 2120.55 1083.79 0.18 6033174.76 660864.58 N 70.49711640 W 148.68445259 6108.28 27.45 25.24 5510.04 2424.56 2160.03 1103.00 1.11 6033214.64 660882.92 N 70.49722426 W 148.68429554 6201.39 27.50 25.47 5592.65 2467.52 2198.85 1121.39 0.13 6033253.84 660900.48 N 70.49733030 W 148.68414508 6295.71 27.55 24.95 5676.29 2511 . 11 2238.29 1139.96 0.26 6033293.67 660918.19 N 70.49743803 W 148.68399323 6388.45 27.20 25.54 5758.65 2553.75 2276.86 1158.14 0.48 6033332.62 660935.54 N 70.49754339 W 148.68384448 6483.57 27.14 26.09 5843.27 2597.18 2315.96 1177.06 0.27 6033372.11 660953.61 N 70.49765019 W 148.68368977 6577.51 27.94 23.68 5926.57 2640.61 2355.35 1195.32 1.46 6033411.89 660971.02 N 70.49775782 W 148.68354039 6671.87 27.98 23.92 6009.92 2684.82 2395.83 1213.17 0.13 6033452.74 660988.00 N 70.49786839 W 148.6833943f 6766.23 27.75 23.63 6093.34 2728.91 2436.19 1230.95 0.28 6033493.47 661004.90 N 70.49797864 W 148.68324891--- 6860.53 27.87 23.92 6176.74 2772.88 2476.45 1248.69 0.19 6033534.1 0 661021.77 N 70.49808862 W 148.68310383 6951.71 27.51 24.17 6257.48 2815.23 2515.15 1265.95 0.41 6033573.15 661038.20 N 70.49819432 W 148.68296261 7047.47 27.24 24.29 6342.52 2859.25 2555.30 1284.02 0.29 6033613.68 661055.40 N 70.49830400 W 148.68281479 7138.86 27.43 24.59 6423.70 2901.21 2593.51 1301.39 0.26 6033652.25 661071.94 N 70.49840837 W 148.68267276 7233.17 28.07 23.96 6507.17 2945.11 2633.54 1319.44 0.75 6033692.66 661089.12 N 70.49851771 W 148.68252510 7327.30 29.10 23.56 6589.82 2990.12 2674.76 1337.58 1.11 6033734.25 661106.37 N 70.49863031 W 148.68237668 7420.57 29.40 22.92 6671.20 3035.66 2716.63 1355.56 0.46 6033776.50 661123.45 N 70.49874470 W 148.68222958 7514.50 28.62 24.20 6753.34 3081.18 2758.39 1373.76 1.06 6033818.64 661140.74 N 70.49885876 W 148.68208068 7608.99 28.31 24.51 6836.41 3126.20 2799.42 1392.33 0.36 6033860.05 661158.43 N 70.49897084 W 148.68192875 NS22 ASP Final Survey.xls Page 3 of 5 3/10/2003-12:39 PM Grid Coordinates Geographic Coordinates Station JD MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n r) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 7697.26 28.23 24.41 6914.15 3168.00 2837.47 1409.64 0.11 6033898.47 661174.92 N 70.49907479 W 148.68178714 7788.95 28.54 24.47 6994.82 3211.58 2877.15 1427.68 0.34 6033938.53 661192.09 N 70.49918319 W 148.68163960 7882.71 28.55 25.09 7077.18 3256.38 2917.83 1446.46 0.32 6033979.59 661209.99 N 70.49929430 W 148.68148598 7976.78 28.52 25.37 7159.82 3301.32 2958.48 1465.61 0.15 6034020.64 661228.27 N 70.49940534 W 148.68132928 8072.65 28.43 24.87 7244.10 3347.02 2999.87 1485.01 0.27 6034062.43 661246.77 N 70.49951839 W 148.68117053 8166.60 28.50 25.57 7326.69 3391.80 3040.38 1504.09 0.36 6034103.34 661264.98 N 70.49962905 W 148.68101444 8260.18 28.97 25.18 7408.74 3436.79 3081.02 1523.37 0.54 6034144.39 661283.38 N 70.49974008 W 148.68085672 8354.60 29.09 24.95 7491.30 3482.61 3122.53 1542.78 0.17 6034186.30 661301.89 N 70.49985345 W 148.68069791 8448.13 28.91 25.11 7573.11 3527.95 3163.61 1561.97 0.21 6034227.79 661320.19 N 70.49996568 W 148.68054095 8541.50 28.61 24.39 7654.96 3572.87 3204.41 1580.78 0.49 6034268.97 661338.11 N 70.50007712 W 148.68038707,~ 8636.11 28.49 25.15 7738.06 3618.08 3245.47 1599.72 0.40 6034310.42 661356.17 N 70.50018927 W 148.68023208 8730.79 28.23 24.95 7821.38 3663.05 3286.21 . 1618.76 0.29 6034351.56 661374.33 N 70.50030057 W 148.68007628 8823.61 27.84 24.24 7903.31 3706.67 3325.88 1636.92 0.55 6034391.61 661391.63 N 70.50040892 W 148.67992771 8917.92 27.98 24.71 7986.65 3750.80 3366.05 1655.21 0.28 6034432.17 661409.05 N 70.50051867 W 148.67977806 9012.33 28.76 24.74 8069.72 3795.66 3406.80 1673.98 0.83 6034473.31 661426.93 N 70.50062997 W 148.67962454 9106.06 28.62 25.31 8151.94 3840.65 3447.57 1693.01 0.33 6034514.48 661445.08 N 70.50074135 W 148.67946881 9199.47 28.37 24.56 8234.04 3885.21 3487.98 1711.80 0.47 6034555.28 661463.00 N 70.50085173 W 148.67931508 9293.06 28.12 24.42 8316.48 3929.50 3528.29 1730.16 0.28 6034595.96 661480.48 N 70.50096182 W 148.67916485 9387.35 27.94 25.36 8399.71 3973.80 3568.48 1748.81 0.51 6034636.55 661498.26 N 70.50107162 W 148.67901227 9482.21 27.96 25.05 8483.51 4018.26 3608.71 1767.74 0.15 6034677.17 661516.33 N 70.50118150 W 148.67885735 9574.97 27.69 25.26 8565.54 4061.56 3647.90 1786.14 0.31 6034716.74 661533.88 N 70.50128855 W 148.67870676 9669.85 28.68 25.08 8649.17 4106.37 3688.46 1805.20 1.05 6034757.70 661552.06 N 70.50139934 W 148.67855081 9762.09 31.10 25.63 8729.14 4152.33 3729.99 1824.89 2.64 6034799.64 661570.85 N 70.50151279 W 148.67838970 9856.82 32.57 26.29 8809.62 4202.30 3774.91 1846.77 1.59 6034845.02 661591.76 N 70.50163549 W 148.67821068 9951.13 34.35 25.79 8888.29 4254.29 3821.63 1869.59 1.91 6034892.22 661613.57 N 70.50176311 W 148.6780239f 10045.37 36.28 26.10 8965.19 4308.76 3870.62 1893.43 2.06 6034941.70 661636.35 N 70.50189691 W 148.67782890~-' 10140.24 36.27 26.63 9041.67 4364.89 3920.91 1918.35 0.33 6034992.51 661660.18 N 70.50203428 W 148.67762493 10234.33 36.42 26.19 9117.46 4420.65 3970.85 1943.16 0.32 6035042.97 661683.91 N 70.50217070 W 148.67742198 10331.20 36.51 26.99 9195.36 4478.21 4022.33 1968.93 0.50 6035094.99 661708.56 N 70.50231132 W 148.67721110 10427.29 37.34 28.14 9272.18 4535.90 4073.50 1995.64 1.12 6035146.72 661734.17 N 70.50245109 W 148.67699248 10521.88 36.89 26.78 9347.61 4592.94 4124.15 2021.96 0.99 6035197.91 661759.40 N 70.50258942 W 148.67677709 10617.87 36.25 26.19 9424.70 4650.13 4175.33 2047.47 0.76 6035249.63 661783.79 N 70.50272923 W 148.67656836 10656.69 35.92 25.93 9456.07 4672.99 4195.87 2057.52 0.94 6035270.38 661793.39 N 70.50278534 W 148.67648615 10804.54 35.81 23.79 9575.89 4759.59 4274.46 2093.93 0.85 6035349.72 661828.11 N 70.50299999 W 148.67618815 10898.24 37.59 21.39 9651.02 4815.50 4326.16 2115.41 2.44 6035401.87 661848.47 N 70.50314121 W 148.67601232 NS22 ASP Final SUNey.xls Page 4 of 5 3/10/2003-12:39 PM ?~ Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10992.96 39.30 20.67 9725.20 4874.20 4381 .13 2136.54 1.87 6035457.28 661868.41 N 70.50329137 W 148.67583939 11089.05 40.29 20.02 9799.03 4935.45 4438.79 2157.92 1.12 6035515.38 661888.54 N 70.50344888 W 148.67566440 11186.13 41.65 20.44 9872.33 4998.82 4498.51 2179.93 1.43 6035575.56 661909.27 N 70.50361202 W 148.67548421 11281.24 42.54 21.46 9942.91 5062.37 4558.05 2202.73 1.18 6035635.57 661930.78 N 70.50377465 W 148.67529758 11377.24 42.76 22.19 10013.52 5127.27 4618.43 2226.91 0.56 6035696.45 661953.66 N 70.50393958 W 148.67509964 11472.45 42.70 23.67 10083.46 5191.80 4677.93 2252.08 1.06 6035756.47 661977.54 N 70.50410209 W 148.67489364 11567.30 42.21 24.92 10153.44 5255.80 4736.28 2278.42 1.03 6035815.37 662002.61 N 70.50426148 W 148.67467806 11662.32 41.93 26.49 10223.98 5319.47 4793.65 2306.03 1.15 6035873.31 662028.98 N 70.50441817 W 148.67445207 11757.98 41.99 26.84 10295.11 5383.41 4850.80 2334.73 0.25 6035931.07 662056.45 N 70.50457429 W 148.67421715 11853.08 41.64 26.80 10365.99 5446.80 4907.39 2363.34 0.37 6035988.25 662083.83 N 70.50472885 W 148.67398300 11948.59 40.52 27.15 10437.98 5509.55 4963.32 2391.81 1.20 6036044.78 662111.09 N 70.50488162 W 148.67375001 .~ 12043.40 40.47 26.46 10510.08 5571.10 5018.27 2419.57 0.48 6036100.31 662137.66 N 70.50503172 W 148.67352276 12140.62 41.17 25.39 10583.66 5634.65 5075.43 2447.35 1.02 6036158.05 662164.21 N 70.50518783 W 148.67329537 12235.59 40.74 24.79 10655.38 5696.89 5131.80 2473.75 0.61 6036214.97 662189.38 N 70.50534181 W 148.67307929 12330.79 40.43 24.34 10727.68 5758.82 5188.13 2499.50 0.45 6036271.84 662213.91 N 70.50549567 W 148.67286852 12423.81 40.51 24.15 10798.44 5819.18 5243.18 2524.29 0.16 6036327.40 662237.51 N 70.50564603 W 148.67266557 12563.65 41.20 24.48 10904.21 5910.63 5326.54 2561.95 0.52 6036411.55 662273.38 N 70.50587373 W 148.67235721 12659.05 40.98 24.59 10976.11 5973.32 5383.58 2587.99 0.24 6036469. 13 662298.18 N 70.50602953 W 148.67214407 12754.43 40.04 22.55 11048.63 6035.23 5440.36 2612.77 1.70 6036526.42 662321.73 N 70.50618461 W 148.67194119 12790.42 40.55 20.94 11076.08 6058.45 5461.97 2621.39 3.22 6036548.22 662329.89 N 70.50624366 W 148.67187061 12887.00 40.55 20.94 11149.47 6121.03 5520.61 2643.83 0.00 6036607.32 662351.06 N 70.50640384 W 148.67168687 -~ NS22 ASP Final Survey.xls Page 5 of 5 3/10/2003-12:39 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska)- Inc. Field....................: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS22 API number...............: 50-029-23128-00 Engineer. . . . . . . . . . . . . . . . .: M. Aburto RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent.......: na DF above permanent.......: 56.51 ft ----- vertical section origin---------------- Lati tude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft, Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 25.75 degrees [(c)2003 Anadrill IDEAL ID6_1C_10J 19-Jan-2003 22:33:07 Spud date. . . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey... ....: MD of last survey........: Page 1 of 6 21-Nov-2002 19-Jan-03 144 0.00 ft 12887.00 ft _c ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2001 Magnetic date............: 30-Nov-2002 Magnetic field strength..: 1150.50 HCNT Magnetic dec (+E/W-) .....: 26.26 degrees Magnetic dip.... .........: 80.94 degrees ----- MWD survey Reference Reference G.. . . . . . . . . . . . . : Reference H.... .... ... ...: Reference Dip...... ......: Tolerance of G......... ..: Tolerance of H..... ......: Tolerance of Dip.........: Criteria --------- 1002.69 mGal 1151.00 HCNT 80.95 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.09 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.09 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)...... ..: No degree: 0.00 ~' · ANADRILL SCHLUMBERGER Survey Report 19-Jan-2003 22:33:07 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (de g) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Dispi +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 0.00 0.76 1.58 2.69 3.35 3.33 2.21 1.50 0.53 0.99 1.75 4.79 6.68 8.13 8.98 11.21 14.01 15.60 17.70 21.88 23.99 25.47 27.14 27.79 28.24 27.83 28.02 27.42 27.40 27.33 0.00 184.47 187.68 187.88 185.25 194.66 192.63 205.80 145.19 76.30 57.02 54.23 45.67 45.96 44.44 39.81 44.20 57.84 54.67 52.01 50.13 49.17 44.44 39.79 35.10 31.97 26.83 25.75 26.64 22.46 0.00 50.00 50.00 50.00 50.00 34.50 29.00 28.00 29.00 39.00 29.00 84.00 93.50 91.00 67.00 113.00 89.00 94.00 93.00 96.00 93.00 95.00 91.00 95.71 93.21 90.30 93.87 96.20 93.65 92.27 [(c)2003 Anadrill IDEAL ID6_1C_I0J 6 7 8 9 10 234.50 263.50 291.50 320.50 359.50 11 12 13 14 15 388.50 472.50 566.00 657.00 724.00 16 17 18 19 20 837.00 926.00 1020.00 1113.00 1209.00 21 22 23 24 25 1302.00 1397.00 1488.00 1583.71 1676.92 26 27 28 29 30 1767.22 1861.09 1957.29 2050.94 2143.21 0.00 50.00 99.99 149.95 199.88 234.32 263.29 291.28 320.27 359.27 388.26 472.11 565.14 655.38 721.64 832.88 919.73 1010.63 lQ99.73 1190.04 1275.69 1361.97 1443.55 1528.49 1610.78 1690.49 1773.44 1858.60 1941.74 2023.69 0.00 -0.31 -1.27 -3.05 -5.53 -7.46 -8.83 -9.72 -10.17 -10.04 -9.50 -5.32 3.22 14.24 23.64 42.65 61.26 82.77 105.74 134.57 167.34 203.67 241.30 283.63 326.47 368.51 412.34 457.08 500.19 542.57 0.00 -0.33 -1.34 -3.19 -5.81 -7.78 -9.14 -10.00 -10.45 -10.52 -10.22 -7.47 -1.39 6.79 13.81 28.55 42.92 57.81 72.65 92.10 114.89 140.63 168.25 200.98 235.72 271.09 309.36 349.47 388.15 426.71 0.00 -0.03 -0.14 -0.40 -0.69 -1.04 -1.37 -1.65 -1.74 -1.31 -0.69 3.23 10.29 18.70 25.77 38.98 52.03 70.67 92.79 118.81 146.98 177.26 206.60 236.17 262.76 286.20 307.76 327.58 346.61 364.22 0.00 0.33 1.35 3.21 5.85 7.85 9.24 10.13 10.59 10.60 10.24 8.14 10.38 19.89 29.24 48.31 67.45 91.30 117.84 150.33 186.55 226.27 266.44 310.11 353.00 394.21 436.37 479.00 520.39 561.02 0.00 184.47 186.11 187.09 186.79 187.59 188.54 189.37 189.45 187.09 183.88 156.62 97.67 70.05 61.80 53.78 50.48 50.71 51.94 52.22 51.98 51.57 50.84 49.60 48.10 46.55 44.85 43.15 41.76 40.48 2 of 6 DLS (deg/ 100f) 0.00 1.52 1.64 2.22 1.35 1.59 3.88 2.94 4.56 2.41 3.03 3.62 2.21 1.59 1.31 2.10 3.32 4.06 2.46 4.45 2.40 1.61 2.94 2.34 2.41 1.69 2.57 0.81 0.44 2.08 ------ ------ Srvy tool type Tool qual type ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR _7' GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ~ ANADRILL SCHLUMBERGER Survey Report 19-Jan-2003 22:33:07 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 2236.70 2329.71 2424.00 2519.45 2612.91 2707.10 2802.04 2899.39 2995.72 3092.54 3188.01 3283.49 3378.92 3474.58 3568.22 3654.29 3764.19 3856.16 3951.04 4043.64 4137.42 4228.61 4322.20 4416.14 4509.64 4603.12 4698.87 4793.04 4884.33 4979.66 26.84 25.84 27.85 29.11 28.91 29.24 29.37 27.55 27.11 27.79 26.16 24.86 25.79 25.69 25.33 29.42 29.88 29.92 29.62 29.20 29.29 28.76 28.65 29.34 29.11 30.03 30.99 31.83 30.81 29.55 20.79 21.93 19.45 20.04 21.10 22.15 22.85 21.37 21.39 22.45 19.60 16.76 17.53 17.76 18.47 22.54 23.11 24.69 23.62 23.28 23.53 23.74 24.44 23.08 24.07 23.68 22.58 23.13 24.46 24.68 93.49 93.01 94.29 95.45 93.46 94.19 94.94 97.35 96.33 96.82 95.47 95.48 95.43 95.66 93.64 86.07 109.90 91.97 94.88 92.60 93.78 91.19 93.59 93.94 93.50 93.48 95.75 94.17 91.29 95.33 [(c)2003 Anadrill IDEAL ID6_1C_10] 2106.93 2190.28 2274.41 2358.31 2440.04 2522.36 2605.15 2690.74 2776.31 2862.23 2947.32 3033.49 3119.75 3205.92 3290.43 3366.85 3462.36 3542.09 3624.45 3705.11 3786.94 3866.68 3948.77 4030.93 4112.53 4193.84 4276.33 4356.70 4434.68 4517.09 585.03 626.17 668.57 713.83 758.97 804.62 851.02 897.31 941.41 985.94 1029.09 1069.84 1110.20 1151.33 1191.30 1230.69 1284.99 1330.80 1377.89 1423.33 1469.11 1513.32 1558.25 1603.76 1649.37 1695.48 1744.04 1793.05 1840.47 1888.39 466.28 504.71 544.54 587.38 629.81 672.36 715.29 758.26 799.45 840.85 881.25 920.29 959.30 998.89 1037.22 1074.22 1124.33 1166.24 1209.23 1250.94 1292.99 1333.52 1374.56 1416.23 1458.07 1500.26 1544.96 1590.18 1633.60 1677.19 379.91 394.94 409.95 425.33 441.25 458.12 475.91 493.38 509.50 526.17 541.73 554.58 566.62 579.21 591.74 605.69 626.78 645.35 664.63 682.73 700.93 718.66 737.01 755.35 773.61 792.28 811.36 830.43 849.57 869.49 601.46 640.87 681.61 725.20 769.01 813.60 859.15 904.65 948.00 991.91 1034.44 1074.48 1114.14 1154.67 1194.14 1233.21 1287.24 1332.89 1379.84 1425.12 1470.75 1514.84 1559.68 1605.08 1650.59 1696.61 1745.05 1793.96 1841.31 1889.17 39.17 38.04 36.97 35.91 35.02 34.27 33.64 33.05 32.51 32.04 31.58 31.07 30.57 30.11 29.71 29.42 29.14 28.96 28.79 28.62 28.46 28.32 28.20 28.07 27.95 27.84 27.71 27.57 27.48 27.40 3 of 6 DLS (deg/ 100f) 0.97 1.20 2.44 1.35 0.59 0.65 0.39 2.00 0.46 0.86 2.18 1.87 1.03 0.15 0.50 5.22 0.49 0.86 0.64 0.49 0.16 0.59 0.38 1.02 0.57 1.01 1.16 0.94 1.35 1.33 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ '~ ANADRILL SCHLUMBERGER Survey Report 19-Jan-2003 22:33:07 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5072.97 5166.47 5260.83 5356.72 5451.22 5542.80 5636.56 5733.46 5823.78 5918.17 6014.32 6108.28 6201.39 6295.71 6388.45 6483.57 6577.51 6671.87 6766.23 6860.53 6951.71 7047.47 7138.86 7233.17 7327.30 7420.57 7514.50 7608.99 7697.26 7788.95 29.42 29.11 28.07 27.88 27.94 28.23 28.04 28.17 28.60 28.34 28.27 27.45 27.50 27.55 27.20 27.14 27.94 27.98 27.75 27.87 27.51 27.24 27.43 28.07 29.10 29.40 28.62 28.31 28.23 28.54 23.99 24.13 25.71 25.88 26.01 26.04 26.51 26.44 26.58 26.94 26.61 25.24 25.47 24.95 25.54 26.09 23.68 23.92 23.63 23.92 24.17 24.29 24.59 23.96 23.56 22.92 24.20 24.51 24.41 24.47 93.31 93.50 94.36 95.89 94.50 91.58 93.76 96.90 90.32 94.39 96.15 93.96 93.11 94.32 92.74 95.12 93.94 94.36 94.36 94.30 91.18 95.76 91.39 94.31 94.13 93.27 93.93 94.49 88.27 91.69 [(c)2003 Anadrill IDEAL ID6_1C_10] 4598.32 4679.88 4762.74 4847.42 4930.93 5011.73 5094.41 5179.88 5259.34 5342.32 5426.97 5510.04 5592.65 5676.29 5758.65 5843.27 5926.57 6009.92 6093.33 6176.74 6257.48 6342.52 6423.70 6507.16 6589.82 6671.20 6753.34 6836.41 6914.15 6994.82 1934.30 1979.99 2025.13 2070.11 2114.35 2157.46 2201.67 2247.31 2290.25 2335.24 2380.82 2424.73 2467.68 2511.27 2553.91 2597.34 2640.76 2684.98 2729.06 2773.02 2815.38 2859.39 2901.35 2945.24 2990.25 3035.78 3081.30 3126.32 3168.12 3211.69 1719.03 1760.77 1801.72 1842.22 1881.99 1920.74 1960.38 2001.24 2039.67 2079.84 2120.54 2160.03 2198.85 2238.28 2276.86 2315.96 2355.35 2395.83 2436.19 2476.45 2515.15 2555.30 2593.51 2633.54 2674.76 2716.63 2758.39 2799.42 2837.47 2877.15 888.42 907.05 926.07 945.64 964.99 983.91 1003.48 1023.83 1043.00 1063.25 1083.79 1102.99 1121.39 1139.96 1158.14 1177.06 1195.32 1213.17 1230.95 1248.69 1265.95 1284.02 1301.38 1319.44 1337.58 1355.56 1373.76 1392.33 1409.64 1427.68 1935.03 1980.67 2025.78 2070.75 2114.97 2158.08 2202.29 2247.93 2290.87 2335.86 2381.45 2425.35 2468.29 2511.86 2554.48 2597.90 2641.30 2685.48 2729.52 2773.45 2815.78 2859.77 2901.70 2945.58 2990.56 3036.05 3081.54 3126.55 3168.33 3211.90 27.33 27.26 27.20 27.17 27.15 27.12 27.11 27.09 27.08 27.08 27.07 27.05 27.02 26.99 26.96 26.94 26.91 26.86 26.81 26.76 26.72 26.68 26.65 26.61 26.57 26.52 26.47 26.44 26.42 26.39 4 of 6 DLS (deg/ 100f) 0.39 0.34 1.36 0.21 0.09 0.32 0.31 0.14 0.48 0.33 0.18 1.11 0.13 0.26 0.48 0.27 1.46 0.13 0.28 0.19 0.41 0.29 0.26 0.75 1.11 0.46 1.06 0.36 0.11 0.34 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ -- ~-' ANADRILL SCHLUMBERGER Survey Report 19-Jan-2003 22:33:07 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 7882.71 7976.78 8072.65 8166.60 8260.18 28.55 28.52 28.43 28.50 28.97 29.09 28.91 28.61 28.49 28.23 27.84 27.98 28.76 28.62 28.37 28.12 27.94 27.96 27.69 28.68 31.10 32.57 34.35 36.28 36.27 36.42 36.51 37.34 36.89 36.25 25.09 25.37 24.87 25.57 25.18 24.95 25.11 24.39 25.15 24.95 24.24 24.71 24.74 25.31 24.56 24.42 25.36 25.05 25.26 25.08 25.63 26.29 25.79 26.10 26.63 26.19 26.99 28.14 26.78 26.19 93.76 94.07 95.87 93.95 93.58 94.42 93.53 93.37 94.61 94.68 92.82 94.31 94.41 93.73 93.41 93.59 94.29 94.86 92.76 94.88 92.24 94.73 94.31 94.24 94.87 94.09 96.87 96.09 94.59 95.99 [(c)2003 Anadrill IDEAL ID6_1C_10J 8354.60 8448.13 8541.50 8636.11 8730.79 8823.61 8917.92 9012.33 9106.06 9199.47 9293.06 9387.35 9482.21 9574.97 9669.85 9762.09 9856.82 9951.13 10045.37 10140.24 10234.33 10331.20 10427.29 10521.88 10617.87 7077.18 7159.82 7244.10 7326.69 7408.74 7491.30 7573.10 7654.96 7738.06 7821.38 7903.31 7986.65 8069.72 8151.94 8234.04 8316.48 8399.71 8483.51 8565.54 8649.17 8729.14 8809.62 8888.29 8965.19 9041.67 9117.46 9195.36 9272.18 9347.61 9424.70 3256.49 3301.43 3347.13 3391.91 3436.89 3482.71 3528.05 3572.97 3618.18 3663.15 3706.76 3750.90 3795.75 3840.74 3885.30 3929.58 3973.89 4018.34 4061.64 4106.45 4152.41 4202.38 4254.37 4308.85 4364.97 4420.73 4478.30 4535.99 4593.04 4650.23 2917.83 2958.48 2999.87 3040.37 3081.02 3122.53 3163.61 3204.41 3245.47 3286.21 3325.88 3366.05 3406.80 3447.57 3487.98 3528.29 3568.48 3608.71 3647.90 3688.46 3729.99 3774.91 3821.63 3870.62 3920.91 3970.85 4022.33 4073.50 4124.14 4175.33 1446.46 1465.61 1485.01 1504.09 1523.37 1542.78 1561.97 1580.78 1599.72 1618.76 1636.92 1655.21 1673.97 1693.01 1711.80 1730.16 1748.80 1767.74 1786.14 1805.20 1824.89 1846.77 1869.59 1893.43 1918.35 1943.16 1968.92 1995.64 2021.96 2047.47 3256.68 3301.61 3347.31 3392.08 3437.06 3482.87 3528.20 3573.11 3618.31 3663.27 3706.88 3751.01 3795.85 3840.84 3885.39 3929.66 3973.96 4018.42 4061.71 4106.52 4152.48 4202.44 4254.44 4308.91 4365.04 4420.80 4478.37 4536.08 4593.14 4650.33 26.37 26.35 26.34 26.32 26.31 26.29 26.28 26.26 26.24 26.22 26.21 26.19 26.17 26.15 26.14 26.12 26.11 26.10 26.09 26.08 26.07 26.07 26.07 26.07 26.07 26.08 26.08 26.10 26.12 26.12 5 of 6 DLS (deg/ 100f) 0.32 0.15 0.27 0.36 0.54 0.17 0.21 0.49 0.40 0.29 0.55 0.28 0.83 0.33 0.47 0.28 0.51 0.15 0.31 1.05 2.64 1.59 1.91 2.06 0.33 0.32 0.50 1.12 0.99 0.76 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ -' ~ ANADRILL SCHLUMBERGER Survey Report 19-Jan-2003 22:33:07 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (de g) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 121 122 123 124 125 10656.69 10804.54 10898.24 10992.96 11089.05 126 127 128 129 130 11186.13 11281.24 11377.24 11472.45 11567.30 131 132 133 134 135 11662.32 11757.98 11853.08 11948.59 12043.40 136 137 138 139 140 12140.62 12235.59 12330.79 12423.81 12563.65 141 142 143 12659.05 12754.43 12790.42 35.92 35.81 37.59 39.30 40.29 41.65 42.54 42.76 42.70 42.21 41.93 41.99 41.64 40.52 40.47 41.17 40.74 40.43 40.51 41.20 40.98 40.04 40.55 Projected to TD 144 12887.00 40.55 25.93 23.79 21.39 20.67 20.02 20.44 21.46 22.19 23.67 24.92 26.49 26.84 26.80 27.15 26.46 25.39 24.79 24.34 24.15 24.48 24.59 22.55 20.94 20.94 38.82 147.85 93.70 94.72 96.09 97.08 95.11 96.00 95.21 94.85 95.02 95.66 95.10 95.51 94.81 97.22 94.97 95.20 93.02 139.84 95.40 95.38 35.99 9456.07 9575.90 9651.02 9725.21 9799.03 9872.33 9942.91 10013.52 10083.46 10153.44 10223.98 10295.11 10365.99 10437.98 10510.08 10583.66 10655.38 10727.68 10798.44 10904.21 10976.11 11048.63 11076.08 96.58 11149.47 [(c)2003 Anadrill IDEAL ID6_1C_10J 4673.09 4759.69 4815.59 4874.28 4935.51 4998.86 5062.40 5127.28 5191.81 5255.81 5319.47 5383.42 5446.82 5509.56 5571.12 5634.67 5696.91 5758.83 5819.19 5910.63 5973.32 6035.22 6058.44 4195.87 4274.46 4326.16 4381.13 4438.79 4498.51 4558.05 4618.43 4677.93 4736.28 4793.64 4850.80 4907.39 4963.32 5018.27 5075.43 5131.80 5188.13 5243.18 5326.54 5383.58 5440.35 5461.97 2057.52 2093.93 2115.41 2136.54 2157.92 2179.93 2202.73 2226.91 2252.08 2278.42 2306.03 2334.73 2363.34 2391.81 2419.57 2447.35 2473.75 2499.50 2524.29 2561.95 2587.99 2612.77 2621.39 4673.19 4759.78 4815.66 4874.33 4935.53 4998.87 5062.40 5127.28 5191.81 5255.81 5319.47 5383.42 5446.82 5509.56 5571.12 5634.67 5696.91 5758.83 5819.19 5910.64 5973.32 6035.23 6058.45 6121.01 5520.61 2643.83 6121.03 26.12 26.10 26.06 26.00 25.93 25.85 25.79 25.74 25.71 25.69 25.69 25.70 25.71 25.73 25.74 25.74 25.74 25.72 25.71 25.69 25.67 25.65 25.64 25.59 6 of 6 DLS (deg/ 100f) 0.94 0.85 2.44 1.87 1.12 1.43 1.18 0.56 1.06 1.03 1.15 0.25 0.37 1.20 0.48 1.02 0.61 0.45 0.16 0.52 0.24 1.70 3.22 0.00 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR D-MAG D-MAG D-MAG D-MAG PROJ ------ ------ Tool qual type ------ ------ --- - ) ) , Date: 02-28;-2003 Transmittal Number:92583 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS-22 01-24-2003 SCH 1 0 12860 JEWELRY LOG GR/CCL;CD v aD~-dca.3 ROM; NS-17 12-15-2002 SCH 50 17170 CEMENT BOND LOG/PRIMARY V" ~Öd.-/lnq DEPTH CONTROL; NS06 06-03-2002 SCH MWD SURVEY REPORT; /' dW"/OJ HARDCOPY/DISKETTE; NS-18 01-05-2003 SCH 15530 16774 JEW ELRY LOG G R/CCL DEPTH v ¡)fi).- Jy I DETERMINATION NS-24 01-06-2003 SCH 11750 12464 JEWELRY LOG; PERFORATING vaDd.-1104 RECORD NS-18 01-12-2003 SCH 14150 14478 GAMMA RAY COLLAR LOG; / .a~~/L1 DEPTH DETERMINATION NS-27 ./ 01-09-2003 SCH 10700 11255 PERFORATING RECORD; ADD dOJ-O~ 1 PERF - 2.875" PJ HSD NS-18 V ~ö~-~RJr SCH 1 14884 16774 REPEAT FORMATION TESTER ~af: £~~ copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates RECEIVED DNR - Division of Oil & Gas Attn: Tim Ryherd FEB 28 2003 AJaeka Oit & Gaa Cons. Comrriteion AndKnge MMS Attn: Doug Choron1anski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ,) ~ O¿;)-åld 3 Date: 03-06-2002 Transmittal Number:92521 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name NS22 Date 01-19-2003 Contract or SCH Log Run 1 Top Depth o Bottom Depth Log Type 12887 MWD SURVEY REPORT; HARDCOPY/DISKETTE ~~ Please Sign and Return ohe copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski RECEIVED FEB 11 2003 Alalia Oii & Gea Cons. CommieIiøn ArtdIcup Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 RE: Redoubt Unit #6 ) ') d·Od - d d-~ Subject: RE: Redoubt Unit #6 Date: Mon, 3 Feb 2003 18:26:42 -0700 From: Rob Stinson <RDStinson@forestoil.com> To: 'Tom Maunder' <tom_maunder@admin.state.ak.us> We are pumping the equivalent of 500 ft of gauge 12 1/4" hole. From my experience, with overgauge hole and contamination, etc, that should give us 200 to 300 ft of good cement to get kicked off. -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Monday, February 03,20034:17 PM To: Rob Stinson Subject: Re: Redoubt Unit #6 Thanks Rob, Where is your planned TOC?? Tom Rob Stinson wrote: > Tom, > > We stuck our BHA last Thursday while drilling 12 114" hole at a depth of > 13,598' MD. We were unable to free the BHA with a fishing string over the > weekend. We backed off last night, leaving the Top of Fish at 13,434' MD. > The rig is currently spotting a cement plug on bottom to kick off and drill > around the lost BHA. > > Robert Stinson > Drilling Engineer - Alaska Division > Forest Oil Corporation > (907)-868-2133 1 of 1 2/3/20034:29 PM ~b:p ) ) Date: 01-27-2003 Transmitt.al Numbcr:926 I 3 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. "-í NS24 12-23-2002 .atB..,lð(f NS24' 12-20-2002 SCH 11350 I V V ___ NS18 12-31-2002 ANA 0 16865 MWD SURVEY REPORT; ôk')rl.- J t/ I v HARDCOPY/DISKETTE; NS22 , 12-12-2002 ANA 0 '12486 MWD SURVEY REPORT; ~~~~ / ,HARDCOPY/DISKETTE; NS24 12-20-2002 ANA 0 '12607 MWD SURVEY REPORT; ¿;ta~/1.o1 v HARDCOPY/DISKETTE; NS~.--- Â.1-~-20®,....-ï /I .-----z~,---z;----~ - ~~.kfK)N--FõR-PmMI-~ / 1/ 1/ {/ V ¿.~ v - - MODIFY; NS12-j /"I ~~~,-..-;,~"-L:...--Z~/vA$L?I19NlgR-'fERMI;:r--T~ ,/ l" ý MODIFY; Top SW Name Date Contractor Log Run Depth NS07 05-06-200~ SCH 1 11418 ~O77 NSo1 05-06-2002 SCH 11418 ( NS07 05-06-2002 SCH 11418 V NS07 05-06-2002 SCH 1 11418 ./ NS07 05-06-2002 SCH 1 11418 /' NS07 05-06-2002 SCH 1 11418 / SCH 1 '1795 ./ ~d ~e£~~y of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Bottom Depth Log Type 11750 GAMMA RAY LOG; MERGED COPY; 11750 PLATFORM EXPRESS; TRIPLE COMBO SSTVD; MERGED COPY; 11750 PLATFORM EXPRESS; NEUTRON/DENSITY; MERGED COPY; 11750 PLATFORM EXPRESS; TRIPLE COMBO; MERGED COPY; 11750 DIPOLE SONIC; MERGED COPY; PLATFORM EXPRESS; HIGH RESOLUTION LA TEROLOG TOOL; '12494 DEPTH DETERMINATION LOG; 11750 12590 REPEAT FORMATION TESTEP.; RECEIVED JAN 3 1 2003 Petrotechnical Data Center LR2-1 900 E, Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Alaaka on & Ge8 ConS. Commillion Andtcnge U.S. Department of the Interi( ') Minerals Management Service (MMS) Submit ORIGINAL plus THREE )es, with one copy marked "Public Information" OMS Control Number 1010-0045 OMS Approval Expires 10/31/2005 APPLICATION FOR PERMIT TO MODIFY (APM) (Replaces Sundry Notices and Reports on Well) 1..JYPE OF SUB,MlTTAL 2. MMS OPERATOR NO.3. OPERATOR NAME and ADDRESS (Submitting Office) ~ REQUEST U SUBSEQUENT 0 CORRECTION 00113 APPROVAL REPORT BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 4. WELL NAME 5. SIDETRACK NO. 6. BYPASS NO. NS22 STOO BPOO ~t... ,,'2,~ 7. API WELL NO. (12 digits) 8. START DATE (Proposed) 9. PRODUCING INTERVAL CODE 50-029-23128-00 01/06/03 S01 WELL AT TOTAL DEPTH (PROPOSED) 13. LEASE NO. 10. WELL STATUS 11. WATER DEPTH (Surveyed) DSI 40' WELL AT SURFACE 12. ELEVATION AT KE (Surveyed) RKB = 56' 16. LEASE NO. OCS-Y0181 ADL 312799 14. AREA NAME 17. AREA NAME Beechey Point Beechey Point 15. BLOCK NO. 18. BLOCK NO. 516 515 19. PROPOSED OR COMPLETED WORK (Describe in Section 22) ~ ~ INITIAL COMPLETION 0 PERMANENT P~"~ o MUL TI-COMPLETION 0 TEMPORAR~NMENT ~ :::~:~:~:~1l0NS 0 PL~TO SIDm~~1\1 o CHANGE ZONE ~ O~R Initial perfora~i~¡~te~"!$ ?OO:j o ACIDIZE WITH COIL TUBING o ARTIFICIAL LIFT (INITIAL) o WORKOVER o CHANGE IN APPROVED PROCEDURE o FINAL LOCATION PLAT ATTACHED 20. RIG NAME OR PRIMARY UNIT (e.g., Wireline Unit, Coil Tubing unit, etc.~l! ~¡r'"J Oi'l 0: G21S,,)Jì,íUII',:) ::1'2\ RIG TYPE !\.la.:;¡I'O Nabors 33E ' Rotary 22. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Attach Prognosis or Summary of Completed woR..{iW~) [ D POST RIG WORK Anchorage, Alaska 1. MIRU slickline. Pull the ball and rod / RHC profile from 'XN' nipple below the new production PéJcke'c3 2. Perforate -140' Ivishak formation between the Top Ivishak and OWC. JAN 2 4 20u 3. Perforate interval based on PE recommendation. Allen Sherritt 26. AUTHORIZING OFFICIAL (Type or Print Name) Floyd Hernandez, (907) 564-5960 28. AUTHORIZING SIGNATURE -~~ REGIONAL SUPERVISOR -:L~..:H'i:i ^ TI("'\.....' 24. CONTACT TELEPHON.~I~~RA~~~~~aMU. ADDRESS (907) 564-52'Ö4" SherriJA@BP.com 27. TITLE 23. CONTACT NAME Senior Drilling Engineer 29. DATE \ /2- Lf/ð 3 THIS SPACE FOR MMS USE ONL Y AP\\~\À) ~\~L/ TITLE e;;/ fú DATE 1/~1 /ð 3 PAPERWORK REDUCllON ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 ~ Requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drining operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. AIl agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currenUy valid OMS Control Number. Public reporting burden for this form is estimated to average 2% hours per response. induding the time for reviewing instructions, gathering and maintaining data. and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230. Minerals Management Service, 1849 C Street. NW.. Washington, DC 20240. MMS FORM MM$-124 (0d0ber2002· Supersede.." previous verslont offonn MM5-124which mqnot be UMCI.) Page 1 of 1 Û.S. "Department of the Interio" . ó?Od -d~3 'M" I M t S . 'OMS) Submit ORIGINAL plus THREE )es, OMB Control Number 1010-0045 Inera s anagemen ervlCt/l with one copy marked "Public Infc.. ...ation" OMB Approval Expires 10/31/200t APPLlCA 1!2~c!2~!A=ot~ce~~!d 12o~2qJ~r R~~WV ~~ 1b¡TYPE OF SUBOMITTAL 2. MMS OPERATOR NO.3. OPERATOR NAME and~tið~~~'S M~bmlttlng Office) IðI REQUEST SUBSEQUENT 0 CORRECTION 00113 APPROVAL REPORT BP Exploration A~~,On1. 2003 4. WELL NAME 5. SIDETRACK NO. 6. BYPASS NO. PO Box 196612 Anchorage, AK~9161'P!ERVISOR FIELD OPERATIoN 11"1: . AAN~GFMeNT SERV"",,,, 10. WELL STATUS 11. ~~~rH 12. ELEVATION AT K( (Surveyed) (Surveyed) 40' RKB = 56' NS22 N/A N/A 7. API WELL NO. (12 digits) 8. START DATE (Proposed) 9. PRODUCING INTERVAL CODE N/A 50-029-23128-00 01/06/03 DSI WELL AT TOTAL DEPTH (PROPOSED) 13. LEASE NO. WELL AT SURFACE 16. LEASE NO. OCS-Y0181 ADL 312799 14. AREA NAME 17. AREA NAME Beechey Point Beechey Point 15. BLOCK NO. 18. BLOCK NO. 516 19. PROPOSED OR COMPLETED WORK (Describe in Section 22) ~ INITIAL COMPLETION 0 PERMANENT PLUGGING o MULTI-COMPLETION 0 TEMPORARY ABANDONMENT o RECOMPLETlON 0 PLUG BACK TO SIDETRACK I BYPASS o MODIFY PERFORATIONS o CHANGE ZONE Ig OTHER Reenter Suspended Operations 515 o ACIDIZE WITH COIL TUBING o ARTIFICIAL UFT (INITIAL) o WORKOVER o CHANGE IN APPROVED PROCEDURE o FINAL LOCATION PLAT ATTACHED 20. RIG NAME OR PRIMARY UNIT (e.g., Wireline Unit, Coil Tubing unit, etc) 21. RIG TYPE Nabors 33E Rotary 22. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Attach Prognosis or Summary of Completed Worl<, As APH~" E I V t D PLEASE SEE ATTACHMENTS. JAN 2 .II 2003 Allen Sherritt 26. AUTHORIZING OFFICIAL (Type or Print Name) Floyd Hernandez, (907) 564-5960 28. A~\;;TURE Alaska Oil & Gas Cons. Cmmnissior, Anchorage 24. CONTACT TELEPHONE NO. 25. CONTACT E-MAIL ADDRESS (907) 564-5204 SherriJA@BP.com 27. TITLE 23. CONTACT NAME Senior Drilling Engineer 29. DATE , I ~ 103 THIS SPACE FOR MMS USE ONLY APP~B\ \ \0û ~~ ~ TITLE Z5ff6 DAi /J /(J ¿ PAPERWORK REDUCTION ACT OF 1195 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 JLøg. Requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approII9 or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandak>ry (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor, and a person is not required to respond to. a œllection of Information unlesa k displays a currenUy valid OMS Control Number. Public reporting burden for this form is estmated to average 2% hours per response. including the time for AWiewing instructions, gathering and maintainil1i3 œ... and completing and reviewing the form. Direct comments regarding the burden esti'nate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Management ServIce. 1849 C Street. N.W., Washington, DC 20240. MMS FORM MMS-124 (October 2002· Supersedes all previous versions of fom MM5-124 which may not be used.) Page 1 of 1 Perforation intervals for N orthstar wells ) ) Subject: Perforation intervals for Northstar wells Date: Fri, 17 Jan 2003 11 :44:09 -0600 From: "Sherritt, Allen" <SherriJA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Francis, Michael J" <Michae1.Francis@BP.com>, "Hernandez, Floyd" <HernanFl@BP.com> Winton, As per our conversation, the following Northstar wells do not have a reference to perforation intervals included in the drilling permits. NS18 NS22 ~O~. - "t. ·1:.....S NS06 NS20 NS16 NS21 NS19 They all will be perforated within the Ivishak interval: "Perforate -1401 Ivishak formation between the Top Ivishak and Owc." "Perforation interval will be based on PE recommendation after completion of well. 11 The actual perforation depths will be provided in the final well completion reports. If you need any further information, give me a shout. Thanks, Allen Sherritt BP Northstar Operations Drilling Engineer * (907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrija@bp.com * (907) 564-5200 (Fax) * MB 3-6 / 383B I ~ ) ) bp ... ,\If.'II, -......~ ~.....- ~~- ~...~ ...~ ~....... ·I'~~I\" ". BP Exploration Alaska Inc. To: Kyle Monkelien I Jeff Walker - MMS Date: January 6th 2003 ,From: Allen Sherritt Northstar Operations Drilling Engineer Subject: Reference: NS22 Application for Sundry Permit - Re-entry Operations. AOGCC Permit #202-223; API #50-029-23128-00 Sundry ap'~roval is requested for the re-entry of well NS22. Operations will be resumed approximately January 9t 2003. Below is an outline of the current status, short operation review of the 7" running and cementing, proposed re-entry, production hole and final completion operations. NS22 SUMMARY DRilLING OPERATIONS Pre-Ria Summary: NS22 was drilled/cased to the top of Sag River formation. The 7" liner is currently set at 12,469' MD into the top of the Sag at 40.5° Inc. at a 24° azimuth. The top of the liner is set at 10,458' MD. The well was left with a 13.3 ppg-KCI Polymer mud in the liner with seawater in the 9 5/8" casing with a 125 bbl (-1700') diesel cap. The 6 1/8" production hole will be drilled to a final TO of -12,8931 MD, (subject to variations in tops.) The final hole angle is tangent at a proposed inclination of 40°, however, the angle should be allowed drop through this section depending on BHA tendencies. During the planning session for this well, lost circulation in the pay-zone was discussed. There is a small probability of encountering sub- seismic faults in the production interval, see fault discussion in the SOR. This well will be a producer completed with 4 'V2" 13Cr-80 solid/cemented liner. Ria Operations: 1. Prepare to re-enter well post IISeasonal Drilling Restriction. " 2. MIRU Nabors 33E. 3. Verify there is no pressure on the tree. NO tree. a. The well was left with a TWC, tested to 4200 psi from below. 4. NU BOPE, pull the tubing hanger and run the test plug. Open annulus valve and test to 250/4800 psi. 5. Pull the test plug. Install the wear bushing. 6. RIH with 4" drillpipe to 2000' MD, circulating/displacing out diesel to the trip tank. Have G&I and rig crew line up Trip Tank#1 sump to G&I disposal pump suction. Coordinate with G&I and circulate one surface-to-surface volume of seawater, monitoring the volume in Trip Tank #1. Continue running in the hole monitoring the quality of the water displaced to Trip Tank#1. When the Mud Engineer is satisfied with the water quality, the hole can be lined up elsewhere on the rig. POOH . See Baroid Mud Program: Well Clean-out/Displacement Procedure. 7 . Test 9 5/8" x 7" liner to 4800 psi for 30 minutes. 8. MU 6 1/8" drilling assembly and run in the hole. 9. A MADD pass for real-time Gamma Ray will be run prior to drilling out 7" float equipment. Running speed through specified intervals should be 50 - 60 fpm (equivalent to 2 samples per foot). At depths / ) ) between these intervals, resume normal running speed. When just above the landing collar, CBU with seawater and high viscosity sweeps. 10. Clean out 7" liner to the landing collar while displacing to new Dril-N fluid system. 11. Drill out remaining cement. Drill 20' of new formation below 7" shoe. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 12. Drill 6-1/8" production interval to proposed TO at 12893' MD (11156' TVD). Increase mud weight to 9.3 ppg prior to POOH. 13. Run and cement the 4-1/2" 12.6# 13Cr liner with an inner string. Set the liner hanger and liner top packer. Circulate a minimum of one bottoms-up to remove excess cement with a 9.3 ppg-viscosified brine. Ensure proper RAMS are run in the BOP for Well Control. . Drill pipe elevators and a TIW crossover from 4 1/2" to DP will be on the rig floor at all times. · When pumping cement, "pump till you bump". If you do not bump the plug, circulate out the cement in preparation for another cement job. Discuss with Anchorage team. 14. Once a successful cement job is obtained, pressure test liner lap to 1500 psi with 9.3 ppg mud to confirm pressure integrity. 15. Change well over to clean seawater thru the inner string (less than 80 NTU's) and by using spacers as per Baroid recommendation. 16. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 17. POOH. Close the blind rams and pressure-test the liner lap to 3750 psi with 8.65 ppg seawater in the well for 30 minutes. Prepare to run the 3 %" completion. 18. Run the 3 %", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. Ensure proper RAMS are run in the BOP for Well Control. Drill pipe elevators and a TIW crossover from 3 1/2" to DP will be on the rig floor at all times. Note: Consider running a gauge ring inside the 4-1/2" liner if prior to running completion string if there are any indications that cement may have been left inside the liner during the cement job and change over to seawater. 19. RIH to packer setting depth. 20. The SCSSSV control line will be run from the Camco TRM 4E tubing retrievable SSSV at +/- 1000' TVD to surface. a. Attach control line to TRM-4E; apply 5000 psi and monitor for 5 minutes. b. Run in well with 5000 psi on line and SCSSV and clamp on to tubing. c. A representative will be on-site while running/testing the TRSSSV. 21. Run space out pups and terminate the 0.25" control line and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function- test the fiber optic line. Land tubing with 5000 psi on control line. 22. Drop ball and rod to set packer. Increase control line pressure to 6000 psi and maintain during packer setting operation and subsequent tubing tests. 23. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 24. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Maintain at least 5000 psi on control line during this operation. Email or fax chart to Drilling Engineer. 25. Bleed down the annulus to 0 psi. Bleed down the tubing to 0 psi. 26. Pressure up on the annulus to shear the RP in the lower most GLM. As we have been having difficulty with the RP shear valve, it is essential this pressure sequence be followed. Pressure up the casing to 2500 psi. Maintain at least 5000 psi on control line during this operation. 27. Release pressure on the casing and the SSSV control line (closing the SSSV). Pressure up on the backside to 1000 psi to test the SSSV from below (through the RP). If ok, bleed pressure to 0 psi. 28. Open the SSSV by pressuring up on the control line. ) ) 29. Pump corrosion inhibitor and heated diesel down the 3 %" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (approximately 4377' MD). RU the U-tubing piping. Maintain at least 5000 psi on control line during this operation. 30. Allow fluids to U-tube from the annulus into the tubing through the lower GLM. Maintain at least 5000 psi on control line during this operation. 31. Set and test the TWC. Close SSSV. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. Attach manifold to control line port on tree, test to 5000 psi, and hold for 10 minutes. If all ok, bleed to 0 psi. . 32. Pull the TWC. Leave the SSSV closed. Ensure all valves are closed. RD and move off well. Estimated Re-entry Date: January 9th, 2003 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/f ") Multibowl 5ksi ' NS22 - Proposed . 1 3 3/8", 68#/ft, L-80, BTC @ 3707' MD ..4 3 1/2", 9.2#/ft, 13-Cr, Vam-Ace TUBING ID: 2.867" ~ CAPACITY: 0.0087 BBUFT 9·5/8" 47# L-80 BTM-C @ 10680' MD H ~- 3.5" X NIPPLE, @ -12269' MD ~ I ORIGINAL KB. ELEV = 56' rB-BF. ELEV = 40.1' 'CB. ELEV = 15.9' 3 1/2" SSSV @ 1000' TVD wi HXO SVLN nipple 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (7253'MD) t.. 31/2" GLM @ 4500' TVD (4949' MD) 31/2" GLM @ 5866' TVD (6500'MD) ~- 7" LINER TOP @ 10457' MD 3.5" Fiber Optic Transducer 3.5" XN NIPPLE, @ -12299' MD -;¡ _ 7" PACKER,13 Cr @ -12279' MD ': 3.5" X NIPPLE, @ -12289' MD B 3.5" WLEG, @ -12309' MD 8' 7". 26#/ft L-80, Hydrll 521 @ 12469' MD JI PBTD @ -12883' MD TD @ -12893' MD i DATE 11/18/02 01/06/03 REV. BY BMH JAS COMMENTS ~S22 Proposed NS22 Completed to Top SAG ~ 4.5" LINER TOP @ -12319' MD ... 4.5",12.6#, 13CrVam Ace North~t:lr WFI I : NS,7,7 API NO: 50-079-73178-00 BP Exploration (Alaska) if ) ) bp .~.., ,\It.'I,, -......'~. ~....~ ~~- --:..~-- ..~ ~..... ·i'''I\- ". BP Exploration Alaska Inc. To: Kyle Monkelien - MMS Date: November 26, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS22 Request Approval to Change Approved Procedure Mr. Monkelien, As stated in the NS22 Application for Permit to Drill (APD), an operational shutdown was to occur at the surface casing point in preparation for the batch completion phase. However, upon reaching surface casing point, ice conditions did not permit the lifting of the drilling restrictions. Therefore, it is requested that we remain on well NS22 and continue to drill to the 9 5/8" intermediate casing point (Top Miluveach) and/or to the 7" intermediate casing point (Top Sag), depending on ice thickness. If you should have any questions or concerns, please contact me @ 564-5791. Sincerely I a:~:::::!IdcI BP Northstar Operations Drilling Engineer 564-5791 RECEIVED NOV 2 7 2002 Alas1<a Oil & Gas Cons. Commissior AnchoraQe .; u.s. Department of the Interiol ) Minerals Management Service (MMS) APPLICATION FOR PERMIT TO MODIFY (APM) -----~ ~ -....-...--') -r--" Submit ORIGINAL plus THREE cop. -""i with ONE copy marked "Public Information" 2{) Z '", 22. ~~ OMB Control Number 1010-0045 OMB Approval Expires 1013112005 1. TYPE OF SUBMITTAL IX! REQUEST 0 SUBSEQUENT HI CORRECTION APPROVAL REPORT 4. WEll NAME (Replaces Sundry Notices and Reports on Well) 2. MMS OPERATOR NO.3. OPERATOR NAME and ADDRESS (Submitting Office) 00113 NS22 N/A N/A BP Exploration Alaska, Inc PO Box 196612 Anchorage, AK 99519-6613 I 10. WELL STATUS 11. WATER DEPTH 12. ELEVATION AT 1<8\ I (Surveyed) (Surveyed) I KBE = 56' : D¡¿L 40' 5. SIDETRACK NO. 6. BYPASS NO. 50-029-23128-00 11/26/02 WELL AT TOTAL DEPTH 8. START DATE (Proposed) 9. PRODUCING INTERVAL CODE '" IA 7. API WELL NO. (12 digits) WELL AT SURFACE. 13. LEASE NO. 16. LEASE NO. OCS-Y0181 ADL 312799 14. AREA NAME 17. AREA NAME Beechey Point Beechey Point 15. BLOCK NO. 18. BLOCK NO. 516 515 19. PROPOSED OR COMPLETED VVORK (Describe in Section 22) o INITIAL COMPLETION 0 PERMANENT PLUGGING o MUL TI-COMPLETION 0 TEMPORARY ABANDONMENT o RECOMPLETION 0 PLUG BACK TO SIDETRACK I BYPASS o MODIFY PERFORATIONS o CHANGE ZONE 0 OTHER o ACIDIZE WITH COIL TUBING o ARTIFICIAL LIFT (INITIAL) o WORKOVER txI CHANGE IN APPROVED PROCEDURE o FINAL LOCATION PLAT ATTACHED 20. RIG NAME OR PRIMARY UNIT (e.g., Wireline Unit, Coil Tubing unit, etc.) Nabors 33E 21. RIG TYPE Rotary 22. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Attach Prognosis or Summary of Completed Work, As Appropriate) "Please See Attachments" 23. CONTACT NAME Barbara Holt 24. CONTACT TELEPHONE NO. 564-5791 25. CONTACT E-MAIL ADDRESS HoltBM @ BP .com 26. AUTHORIZING OFFICIAL (Type or Print Name) Floyd Hernandez, 564-5960 27. TITLE Senior Drilling Engineer 28. AUTHORIZING SIGNATURE ~ , n 29. DATE ~ \\,'~«o~ THIS SPACE FOR MMS USE ONL Y --------------------------------------------------------~--------------------------------------------------.---------~------------------------- APPROVED BY : TITLE : DATE ~. \\"'~~ i"'~ ~J-. 'I Ìì I 0-z PAPERWORK REDUC110N ACT OF 1195 (PM) STATEMENT: The PM (<44 U.S.C. 350111 H!1. requires us to Worm you that we coiled this Rormation to obtain knowledge of ~ and proc:edwes to be used in drilling weIk:ompletion, wortuwer. .-.d procIuction operations. MMS uses the I1formation to evaluate .-.d 8P\X'O'I8 or disapproYe the adequacy of the ~ w:v:J/0( proc:edwes to safely perform the proposed openItion. Responses are I1'Ia'Idatoty (<43 U.S.C. 1334). ~ data are CXMM'ett under 30 CFR 250.196. Ñ\ agency may not conduct or sponsor. and a person is not required to respond to, . collection of information U'IIess it displays . CUTentIy valid OMS Control Nc.Mnber. Public reporting burden for this form is estimated to average 1 Y4 hotn per response, ndudng the time for reviewing instructions, gathering end maiUining data, and completing and nwiewing the form. Direct c.ommerts regarding the burden estimate or any OCher aspect d this form to the Information CoIIeåion CIearanoe 0I'f108l'. Mail Stop "230, Minerals Management Service. 1~9 C Street, N.W.. Washington. DC 2020i0. M M S FORM MMS-124 (October 2002 - Supersedes aU previous versions of fonn MMS-124 which may not be used.) Page 1 of 1 ) ~7-7~~ ) United States Department of the Interior MINERALS MANAGEMENT SERVICE Alaska Outer Continental Shelf Region 949 East 36th Avenue, Suite 300 Anchorage, Alaska 99508-4363 NOV 2 0 . 2002 Mr. Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. 900 East Benson Blvd. Anchorage, AK 99508 RECEIVED NOV 2 2 2002 AlasRa on & Gas Gons. Conil " Anchorage The Application for Permit to Drill (APD) for NS-22, Northstar Development Project, is hereby approved, subject to the conditions stated in this letter. Also enclosed is a signed copy of the APD (enclosure I). The API number will be issued by the State of Alaska AOGCC for the NS-22 development well. Dear Mr. Hernandez: State approval of an APD for this well is required prior to the start of operations for NS-22. This well, meets the criteria established for the diverter departure approved on October 13, 2001, therefore no diverter will be required during the drilling of the surface hole portion of the well. Your request to set the Blowout Prevention Equipment (BOPE) test pressure at 4800 psi is hereby accepted. The Northstar reservoir has been classified, as required under 30 CFR 250.417 (c), as hydrogen sulfide ,absent, therefore no hydrogen sulfide contingency plan is required for this well. Well information for this well will be submitted as specified in our letter of March 26,2001 and modified on November 15,2001. The formation markers section of the supporting documentation indicates that two faults will potentially be drilled during this well. Please note this and any preparations needed during this time in the "Summary of Drilling Hazards" to be posted at the rig. This office plans to conduct periodic -inspections of the drilling operations and anticipates the need to utilize BP Exploration (Alaska) Inc. (BPXA) transportation and lodging. As allowed in 30 CFR 250.133, BPXA may request reimbursement for the cost of transportation and lodging provided for Minerals Management Service personnel. Your request must be submitted within 90 days of the inspection. 2 Mr. Floyd "randez Senior Drilhug Engineer ') After office hours, weekends and holidays, all calls related to drilling activities or changes to the approved APD should be made to Mr. Kyle Monkelien at the following numbers: Home. Cell Phone 907-349-5083 907-250-0546 If you should have any questions regarding this approval during nomal business hours, please call Mr. Monkelien at 907-271-6431. Sincerely, I\~\_\\\ ' \ \ ,) ~\~\0- /~--_/ Je~ey , alker Regional Supervisor, Field Operations Enc1osure(s) L: Tom Maunder, Senior Petroleum Engineer, AOGCC ) ~7~Trí ~J !Æ~!Æ~~~fÆ / AI~ASKA. OILA5D GAS / CONSERVATION COMMISSION '} TONY KNOWLES, GOVERNOR 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Unit NS-22 BP Exploration (Alaska) Inc. Peffilit No: 202-223 Surface Location: 1259' NSL, 646' WEL, SEC. 11, TI3N, R13E, UM Bottomhole Location: 1487' NSL, 3265' WEL, SEC. 01, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required peffilits and approvals have been issued. In addition, the Commission reserves the right to withdraw the peffilit 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 teffils and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~cfL~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED thiS..2D~day of November, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. 12. Distance to nearest property line 13. Distance to nearest well /' OCS-0179, 488' MD (APPROX.) NS20 is 1.52' away at 600' MD 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size . Casino Weioht Grade COUDlino 20" 169# X-56 WELD 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-Mod 7" 26# L-80 Hydril521 4-1/2" 12.6# 13cR Vam Ace Hole 20" 16" 12-1/4" 8-1/2" 6-1/8" ) STATE OF ALASKA ) ALASK.I"'\ JIL AND GAS CONSERVATION COMtvllSSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 56' Northstar Unit 6. Property Designation OCS-Y0181 7. Unit or Property Name Northstar Unit 8. Well Number / NS22 Number 2S100302630-277 9. Approximate ~púgJdate ufS11Ó2 Amount $200,000.00 14. Number of:ãires in property 15. Proposed depth (MD and TVD) 2252 12893' MD /11156' TVD o 17. Anticipated pressure {S~ 20 AAC 25.035 (e) (2)} 40 Maximum surface 3848 psig, At total depth (TVD) 11100' / 5180 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 201' 201' Driven Surface Surface 3699' 3406' 539 sx PF IL', 466 sx Class 'G' Surface Surface 10550' 9361' 719 sx Econolite, 565 sx Class 'G' 10400' 92471 12534' 10881' 419 sx Class IG' 12384' 10766' 12893' 111561 75 sx Class IG' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1259' NSL, 646' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1238' NSL, 33791 WEL, SEC. 01, T13N, R13E, UM At total depth 1487' NSL, 32651 WEL, SEC. 01, T13N, R13E, UM Lenath 2011 3699' 10550' 2134' 509' Quantitv of Cement (include staoe data) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Barbara Holt, 564-5791 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd HernandeC- ~ ~ Title Senior Drilling Engineer Date >cQ.$$¡~.iU$.:OntY>,.····:· Permit Number API Number . Appr9~~ D~Y; See cover letter Zð¿ - Z .2..~ ~ 50- Q.z. 9'.... 2. 3 i :2. 'Z I¡ I~OII) J--- for other reauirements Conditions of Approval: Samples Required 0 Yes II No Mud Log Required HI Yes 0 No Hydrogen Sulfide Measures ŒI Yes 0 No Directional Survey Required J8I Yes 0 No Required ~orking ~ressure. for ~OPE " [J 2K 0 3~ 04K ....0 5K I:] 1 O~ 0 15K ~ 3.5K p,si for ~TU. Other:lëst &Jèt to '1-8.100 fÇ.1 . {Iol'" ZoML lS.o;~ (Á)/z.JJ d.¿"è-y'~y V€,:,K.t'-(Wli'4{".t W~ \K!~. ORIGINAL SIGNED BY by order of 0 ~" ~ £ Approved By M l. Bill ;.5?0~miSS~~~r I' " "the commission Date II cqO/C?~ Form 10-401 Rev. 12-01-85 ~ .~ I') fj II _.1>,_ 'i I,',.....i,,'~ ~ S bmlt In Tnpllcate \.) ~ \ Q l) ~ ~ \j i~·\ L '1 ) ) J' bp .,. ,\lr.,,,, ..........~ ~...- ~- ~..-- *.'\ -F"". ·'I'·~I\· ". BP Exploration Alaska Inc. To: Winton Aubert· AOGCC Date: November 18, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS22 Application for Drilling Permit Mr. Aubert, NS22 is currently scheduled for Nabors 33E on November 21 st, 2002. / The NS22 well path intersects the Area of Review for a proposed disposal well NS32, much the same circumstance as well NS07 and the NS10 Area of Review. Well NS32 has not been drilled; however, a proposed well path exists. The EPA permit for NS10 Area of Review states "New wells within the area of review shall be constructed in accordance with the AOGCC Regulations Title 20-Chapter 25. Further, all wells in the Area of Review shall have casing cemented to the formation throughout the entire section from /' · t the base of the lower confining zone to the top of the upper confining zone". Though NS32 is not yet drilled, :c~~l this EPA permit will be followed in case the NS32 well is d~lIed. There fore, cement will be brought from the 9 5/8" casing shoe to the top of the SV6 confining shale. "'this ation top is located inside the 13 3/8" casing. In order to both cement and freeze protect this ann s, down-squeeze must be performed. It i~ requested the 13 3/8" casing seat be located at 3,699' MD ,4 TVD in the SV5 (rather than in the SV6 shale). This will increase the certainty of which formation ~..,. reak down (SV5 sand) during the down squeeze, thus increasing certainty in forma. tion coverage. Excessive gas is not an issue i~S ~hallow sand. The maximum amount of gas found in the SV5 since BP Northstar drilling began has bee 45 its. /' A Diverter waiver is requested on NS22. To date, BP has drilled nineteen development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with~.shallow gas. Eighteen surface holes have been drilled and cemented to a common depth of appro~i . ely/8, 170' TVDss depth, (-150' TVD below the top of the SV6), with one well extending into the SV5 328 TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. NS22 will perform an "Operation Shutdown" during the 2002 Seasonal Drilling Restriction period. A Sundry for the Operation Shutdown will not be submitted, as the operations are covered in the ADP procedure. Please find attached the NS22 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5791. Sincerely, å¿~P- BP Northstar Operations Drilling Engineer 564-5791 ) ) NS22 SUMMARY DRilLING OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ASS Vetco landing ring for the ASB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ria Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" d~rter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-60' TVD below the top -1- of the SV5 marker at approximately 3628' MD. ¡'Surface casing point has been picked at 3699' MD. POOH. ~. 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. No TAM port collar will be run. The risk of leak, and potential loss of hole, far outweighs !þe likelihood of not getting cement to surface in one stage. ~ 5. Displace cement with 9.4 ppg brine. Bump plug and hold 500 psi for casing integrity. RIH with drill pipe with closed TIW valve to displace 200' MD (-30 bbls) of seawater. POOH. 6. ND diverter / riser system and NU casing / multi-bowl wellhead. 7. RU truck to pump diesel freeze protect. 8. Shut down and monitor the well for a minimum of 30 minutes. POOH / 9. Prepare for IIOperations Shutdown. (June 1st Seasonal Drilling Restriction)" 10. Install 4 %" tubing hanger and test to 500 psi. 11. Set the TWC. NU Tree. Test the tubing head adapter and tree to 500 psi. 12. Install (dry rod in) SPV and test. Ensure all valves are closed. RD and move off well. 13. Prepare to re-enter well post IISeasonal Drilling Restriction. 11 14. MIRU Nabors 33E. / 15. Pull BPV. Install TWC. ND dry hole tree. NU BOPE and test to 250/4800 psi. / 16. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 17. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a minimum of 11.0 ppg EMW. (FIT/LOT procedure on file with AOGCC). /' 18. Drill 12-1/4" intermediate hole to casing point (approximately ~550' MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.3 ppg at the top of Kuparuk. POOH. (No logs will be run, unless the Kuparuk is oil bearing.) 19. Run 9-5/8",~7# intermediate casing. Cement the casing to the top of the SV6 confining shale in a ~rt single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with no more than 1 annular volume of mud upon installing and testing the packoff. 20. Down-squeeze cement sufficient to cover the SV6 shale, followed by a spacer and diesel to 2000' /" TVD for freeze-protection. WOC. // 21. MU 8-112" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4100 psi with 10.3 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 22. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a minimum of 12.8 ppg EMW, .fIT/LOT procedure on file with AOGCC). 23. Weight up to minimum 12.5 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 12,489' MD. Intermediate casing point has been picked at 12,534' MD. POOH. NS22 Permit to Drill ) ') / 24. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 25. POOH and lay down liner running tools. Test 9 5/8" x 7" liner lap to 2000 psi for 30 minutes with 12.8 ppg fluid (or 3555 psi with 9.1 ppg fluid). 26. RIH w/6-1/8" directional assembly. Displace to 9.1 ppg mud. Clean out 7' liner to the landing collar. 27. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1 ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). / 28. Drill 6-1/8" production interval to the proposed TD at 12,893' MD. Increase mud weight to 9.3 ppg prior to POOH. 29. Make a clean out run, if requi,d, and condition the hole for a liner. POOH. 30. Run and cement the 4-112" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate a minimum of 1 (one) bottoms up to remove excess cement with 9.3 ppg viscosified brine. · In the event the Sag River tops comesfin deep, the well will be drill~d aSiVhoriz~al, completed with a 4 %" 12.6# 13Cr slotted liner. A Sundry will be submit~d ~tJRsf time. 31. Circulate to clean seawater (less than 80 NTU's) using spacers as per Baroid rJeeñfñíe~dation. 32. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). ...-"'" 33. POOH. Close the blind rams and pressure-test the liner lap to 3750 psi with 8.65 ppg seawater in the well for 30 minutes. Prep?e to run the 3 %" 9.2# 13Cr completion. No slick line work will be done. 34. Run the 3 %", 9.2# 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 35. RIH to packer setting depth. The TRM-4E Camco SSSV control lines will be run from the TRSV at +/- 1000' TVD to surface. 36. Run space out pups and terminate the 0.25" control line and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function- test the fiber optic line. 37. Pump corrosion inhibitor and heated diesel down the 3 %" x 9 5/a" annulus equivalent to the ~Ius capacity plus tubing capacity to a depth of 4000' TVD (4387' MD). RU the U-tubing manifold. 38. Drop ball and rod to set packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. /' 39. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 40. Bleed down the annulus to 0 psi. Bleed down the tubing to 0 psi. 41. As we have had difficulty with the RP shear valve, it is essential the pressure sequence be followed. Pressure up the annulus to 2500 psi. This will shear the RP valve in the lower most GLM. /" 42. Bleed off annulus to 0 psi. 43. Allow fluids to U-tube from the annulus into the tubing through the lower GLM, -6500' MD. 44. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 45. Install and test (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: November 215\ 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 2 NS22 Permit to Drill ) ") NS22 WELL PLAN SUMMARY I Type of Well (producer or injector): I Producer NS22 1259' FSL, 646' FEL, Sec. 11, T13N, R13E, UM X = 659827 Y = 6031032 1238' FSL, 3379' FEL, Sec. 1, T13N, R13E, UM X = 662256 Y = 6036345 10,830' TVDrkb 1487' FSL, 3265' FEL, Sec. 1, T13N, R13E, UM X = 662365 Y = 6036596 11 ,156' TVDrkb I AFE Number: 1831326 -",/) I 1 Rig: 1 Nabors 33E ,,," / I Estimated Start Date: 111é'1ffi)2 / I Operating days to complete: ./ I MD: 112,893 I I TVDrkb: 111,156 I I RKB/Suñace Elevation: (a.m.sJ.) Northstar Slot: Suñace Location: Target (top of SAG): 300' Radius Bottom Hole Location: I Well Design (conventional, slim hole, etc.): I Modified Big Bore I Objective: Ivishak Producer with fiber optic surveillance control line Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS22 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 of @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20", 169#, X-56 (pre-driven) 3 /' I 131.8 I I 56.0' / 15.9' I I 1 NS22 Permit to Drill ) ') MUD PROGRAM: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3699' MD /3406' TVD (-60' TVD below top SV5). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec Initial 8.8-9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 >6 15 - 25 6-10 8.5 - 9.5 SV6 @ Interval TD *9.5 / 75 - 100 20 - 35 >6 10 - 25 6 -10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer From Surface Casing Shoe to 10,550' MD /9361' TVD. Interval Density (ppg) PV Initial 8.7 - 9.3 10 -16 Top HRZ 10.3 / 10 - 16 Top Kuparuk to Miluveach 10.3 10 - 18 12-1/4" Hole Section YP 20 - 30 20 - 25 20 - 28 Tauo API/ HTTP FL 4-7 6-10 4 - 7 4-6 / <12 4-7 4-6/<12 pH 8.5 - 9.5 8.5- 9.5 8.5-9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 9" Hole Section From Intermediate Casing Shoe to 12,534' MD /10,881' TVD (top of Sag) Interval Density (ppg)j PV YP Tauo API FL pH Miluveach & Kingak to top of Sag 12.5 - 13.0 25 - 30 20 - 30 4 - 8 4-6 / <10 8.5 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 12,893' MD /11,156' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 8 - 12 20 - 25 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P20) KOP: Maximum Hole Angle: Close Approach Wells: Survey Program: ±300' MD ca,ft'enary curve 1.50°/100' to 2.50°/100' build ±40.00° Surface- 10' well spacing to well NS21; NS20 is 1.52' at 600' MD (major risk). Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1000'. Standard MWD surveys from +/-1000' to TD. IFR will not be utilized. SURFACE AND ANTI-COLLISION ISSUES: All wells pass the major risk rule. Gyros will be run from surface to -1000' MD or until reliable MWD surveys can be taken. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 4 Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3699' MO /3406' TVO (-60' TVO below top SV5). Interval Density Viscosity YP (ppg) (seconds) 8.8 - 9.0 100 - 200 *9.0 - 9.5 100 - 200 *9.5 75 - 100 ,,- " * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary.l/ I Intermediate Hole Mud Properties: Seawater Polymer 12-1/4" HOle~ction From Surface Casing Shoe to 10,550' MO /9361' TVD. /" 4' Interval Density (ppg) PV YP Tau/, API/ HTTP FL Initial 8.7 - 9.3 10 - 16 20 - 30 4 ""jl'7 6 - 10 Top HRZ 10.3 10 - 16 20 - 25 4"'~ 7 4-6/ <12 Top Kuparuk to Miluveach 10.3 10 - 18 20 - 28.,/'4. - 7 4-6/ <12 (;,l Drilling Liner Hole Mud Properties: Inhibited KCL /","""'9" Hole Section From Intermediate Casing Shoe to 12,534' MD /10,881' TVD (top of Sag) ¡'.,/' Interval Density (ppg) PV ,/' YP Miluveach & Kingak to top of Sag 12.5 - 13.0 25 -,,3'Ö 20 - 30 ,,/ 'i' Production Hole Mud Properties: Seawater/CaC03 DrJ,(í-ln Fluid From Intermediate Casing Shoe to 12,893' MD /11, 1 ~,ttTVD " Interval Density (ppg) PV >",..l'/ YP Initial/Final 9.1 - 9.3 8 - 12,~,/" 20 - 25 J~' ' l ,/ / /' / ±300' MQ,,,éantenary curve 1.50°/100' to 2.50°/100' build /' Maximum Hole Angle: ±40.0,-W Close Approach ~ace- 10' well spacing to well NS21; NS20 is 1.52' at 600' MD (major risk). Wells: ¡/Gyro will be used for initial surveys and kickoff Survey Program: / Gyros as required from surface to +/-1000'. I Standard MWO surveys from +/-1000' to TO. IFR will not be utilized. / /1 SURFACE AND ANTI-COLLISION ISSUES: "'./ All wells p~S~he major risk rule. Gyros will be run from surface to -1000' MO or until reliable MWO surveys ,¿an be taken. NS22 Permit to Drill MUD PROGRAM: Initial from -1555' SV6 @ Interval TO 50 - 70 30 - 45 20 - 35 DIRECTIONAL:(P20) KOP: ') Tauo Gel 10 sec 25 - 40 15 - 25 10 - 25 /' / API F¡/ pH 15 -¡/20 8.5 - 9.5 6/10 8.5 - 9.5 ,6 - 10 8.5 - 9.5 >8 >6 >6 pH 8.5 - 9.5 8.5-9.5 8.5-9.5 Tauo 4-8 APIFL 4-6/ <10 pH 8.5 - 9.5 6-1/8" Hole Section Tauo 4-7 API FL 3-5 pH 8.5 - 9.5 l/ Surf~ce Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. "./i / / / / / i I ) 4 NS22 Permit to Drill " ) LOGGING PROGRAM: 16" Section: Drilling: GRlDirectional - Gyro as needed to -1000' MD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GRlDirectional, Resistivity (real-time), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 9" Section: Drilling: GRlDirectional, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GRlDirectional, Resistivity/Density/Neutron (recorded) Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None Intearitv Testina: Test Poi nt Depth Shoe Test Type FIT FIT FIT EMW Estimated Casing/Liner Test 3500 psi w/9.3 ppg 4100 psi w/10.3 ppg 3555 psi w/ 9.1 ppg 3750 psi w/ 8.65 ppg ~ 13 3/8" Surface 95/8" Intermediate 7" Drilling Liner 4 %" Production Liner 20' min from 12 1/4" shoe 20' min from 9 5/8" shoe 20' min from 7" shoe 11.0 ppg EMW Target 12.8 ppg EMW Target 11.5 ppg EMW Target CASINGITUBING PROGRAM: Hole Size Casing/ WtlFt Gr,de co",. Casing Casing Top Hole Btm Tbg a.D. Length MDITVDrkb MDITVDrkb 20" 20" 169# X-56 WELD 201' Surface 201 '/201' 16" 13 3/8" 68# L-80 BTC 3699' Surface 3699'/3406' 12 ~" 9 5/8" 47# L-80 BTC-Mod 10550' Surface 10550'/9361 ' 8%" 7" 26# L-80 Hydril521 2134' 10400'/9247' 12534'/10881' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 509' 12384'/10766 12893'/11156' Tubing 3-1/2" 9.2# 13Cr Vam Ace 12384' Surface 12384'/10766' 5 NS22 Permit to Drill ) ') FORMATION MARKERS: TVDss MDrkb Pore Press. Comment Formation Top estimated (Psi) (ppg EMW) Top Permafrost 1,149 1218 542 8.65 Base Permafrost 1,519 1613 708 8.65 SV6· top confining zone 3,015 3317 1381 8.65 ~ SV5 . base confining zone 3,287 3628 1504 8.65 S ({¡y'{ . t7~ Suñace casing point 3,350 3699 SV4 3,597 3982 1643 8.65 SV2 ... top upper injection zone 3,922 4353 1789 8.65 SV1 ... top major shale barrier 4,412 4912 2010 8.65 TMBK... top lower injection zone· Top Ugnl 4,793 5347 2181 8.65 WS1 ... top Schrader Bluff... Base Ugnu 6,398 7180 2903 8.65 :M3 ... Base lower injection zone (top ColvillE 6,887 7739 3123 8.65 THRZ ... Top HRZ 8,777 9897 3973 8.65 BHRZ... Base HRZ 8,837 9966 4000 8.65 Top Kuparuk 8,897 10037 4265 9.22 Kuparuk C 9,101 10286 4428 9.36 Unnamed fault - 50' throw 9,180 10386 (0. ) Top Miluveach 9,269 10503 Intermediate casing point 9,305 10550 Intermediate logging point 9,305 10550 Top Kingak 9,791 11184 Fault 49s1 - throw = 80' 10,098 11585 Top Sag River 10,791 12489 5048 8.95 I~.O Geol target #1 10,774 12467 5015 8.95 Geologic Target #1 300 ' radius Intermediate casing point 10,825 12534 Top Shublik - 90 10,900 12632 5099 8.95 Top Ivishak 10,990 12749 5141 8.95 Total Depth 11 ,1 00 12893 5192 8.95 owe estimated from Seal A-1, Oil ... Water contact 11,100 12893 5176 8.95 A-2, A-3, NS #1, NS27, NS31 Total Depth 11 ,1 00 12893 5180 8.93 Top Kavik Top Lisburne 6 NS22 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ) 3699' 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 10550' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 174 - 9 5/8" x 12" 2134' 1-8 %" 1-7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1-7" 509' 1 - 4-112" 1 - 4-112" 12 - 4-1/2" x 5-3/4" 12- 4-1/2" x 5-3/4" 1 - 4-112" x 7" 1 - 4-1/2" x 7" 1 - 4-112" 12384' 1 1 1 1 1 1 1 1 1 2 1 ') 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing Head/Tbg head 9 5/8", 47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7",26# L-80 Hydril 521 BBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger - Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-112",12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 3-1/2",9.2# 13Cr-80 Vam Ace 3 %" ABB-VGI tubing hanger 3 %" ABB- VG I adapter flange 3 %" ABB-VGI 5-1/8" 5K Swab Valve wI tree cap CIDRA mandrel and 0.25" fiber optic cable (wI 4 %" cable clamps). 3 %" TRSV and 0.25" control line 3 %" x 1 %" GLM with dummy valve installed 3 %" x 1 %" GLM with RP Shear valve installed 7" x 3 %" Baker 13 Cr packer S-3. 3 %" WLEG (wlo holes) 3 %" 13 Cr X nipples 3 %" 13 Cr XN nipple 7 NS22 Permit to Drill ) ') PERMAFROST: The 13-3/8" surface casing will be run approximately 1800' TVD below the permafrost to -3699' MD / 3406' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a Permafrost 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 20 'cased hole capacity from surface to 200' MD, 3026' of Open Hole + 100% excess from the perm 6St surface + 50% excess to 750'MD above the shoe. Lead TOC: rfa Tail: Based 0' of 16" open hole x 133/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2949' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alp pacer weighted to 1.0 ppg over mud weight 398 bbll sk I 2237 ft of 10.7 ppg Permafrost 'L' Cement. 4.15 cfls '" ST 50° I BHCT 50°, TT = 6.0 hrs 96 bbl t ~6 .sk I 541 ft;.1 of 15.8 ppg Premium 'G' w/ 2% CaCI2. 1.16 cf ,BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate I Basis: Stage 1: Lead: Based on. 5~J...' of 12 1/4" open hole x 9 5/8" csg with 30% excess Lead TOC: At --:-$3y(' MD (3071' TVD) Tail: Based on ~¡ of 12 %" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -9037' MD (8080' TVD) IStage 1: Total Cement I Spacer Preflush Spacer Lead 20 bbls sea water 50 bbl Alp!Ja1pacer wei~hted to 1.0 ppg over mud MW 415 bbl I œ-~k 12330 ft of 11.2 ppg Econolite. 3.24 Cf/S~ T 210° I BHCT 130° TT = 4.0 hrs 116 bbl ~k I 650 ff:! of 15.9 ppg Premium 'G'. 1.15 cfls ,BHST 210° / BHCT 130°, TT = 4.0 hrs Tail Casing 17" Drilling Liner Basis: Stage 1: Slurry: Based on 198' 9" open hole x 7" csg with 50% excess + 150' 9 5/8" csg x 7" csg liner lap + 20C 9-5/8" csg x 5" drill . e bove TaL + 80' shoe joint. Slurry TOC: At - 04 'MD (9247' TVD) Stage 1: Total Cement 1 er Spacer 50 bbl AI~pacer w~ighted to 1.0 ppg over mud MW Slurry 114 bbl / 1k / 629 ft;.1 of 15.9 ppg Premium 'G'. 1.50 cf/sk, HST 250° I BHCT 150°, TT = 4.0 hrs Casing 14-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 359' 6 1/8" open hole x 4 %" csg with 50% excess + 150' 7" csg x 4 %" csg liner lap + 200' 7" csg x 4" dril ipe ¡above TaL + 80' shoe joint. Slurry TOC: At - 3 MD (10766' TVD) Stage 1: Total Cement / S 'er Spacer 35 bbl ¡..", Spacer weighted to 1.0 ppg over mud MW Slurry 20 bbl /76 sk /114 ftJ of 15.9 ppg Premium 'G'. 1.50 cf ;/BHST 250° / BHCT 150°, TT = 4.0 hrs 8 NS22 Permit to Drill ) ') WELL CONTROL: ~ A Diverter waiver has been requested on well NS22. To date, BP has drilled 19 development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. Most (18) of the surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4800 psi. / Suñace Section: · Maximum anticipated BHP: 1504 psi @ 3287' TVDss - SV5 · Maximum surface pressure: 1110 @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 910' TVDss - Kuparuk 'C' · Maximum surface pressure: 3336 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Drilling Liner Section: · Maximum anticipated BHP: 5048 psi @ 10791' TVDss - Sag River · Maximum surface pressure: 3753 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Production Section: · Maximum anticipated BHP: Ei1 ,'-., si@11100'TVDss-TotaIDepth · Maximum surface pressure: 4 si @ surface (Based on BHP and a full column of rom TD @ 0.12 psi/ft) · Planned BOP test pressure: 4800 psi (annular to 3500 psi) / · Planned completion fluid: 8.5 ppg Seawater /6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./ No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ./ No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. DISPOSAL: / Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. 9 NS22 Permit to Drill " ') · ,//) ~.- / SURFACE HOLE SECTION: Mu ogg ~ will be rigged up throughout the entire section. No . /Ificant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud. Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS21 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. · · · · · · ~..---- ,//' INTERMEDIATE SECTION: fv)~IOg s will be rigged up throughout the entire section. MJ ., ."gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. A small, unnamed fault will be encountered in the Kuparuk Formation. Penetration is expected at - 9180 TVDss +/- 200' TVDss. Displacement on this fault at the pOint of penetration should be less than 50 feet. This fault has not been penetrated by any other well. Risk of fault-related drilling problems associated with this fault is unknown. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. See SOR for more details. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. ~-l The kick tolerance for the 12 1/4" open hole section would be '0~,.'2,.bbls assuming an influx from the Kuparuk interval at -8953 TVD. This is the worst-ca _." 'ario based on a 9.84 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, racture gradient (FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.3 ppg mud in the hole. · · · · · · · 10 NS22 Permit to Drill ') ') · ~.-- ,;/ dlog9,~ . will be rigged up throughout the entire section. r s""'" While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Gas in the Sag is possible. Circulate as required. According to Geology, the top of the Sag is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. Fault 49s1 will be encountered in the upper-half of the Kingak shales. Penetration is expected at - 10098 TVDss +/- 200' TVDss. Displacement on this fault at the point of penetration should be less than 80 feet. Fault 49s1 has not been penetrated by any other well. Risk of fault-related drilling problems associated with this fault is unknown. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig~ The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 14.0 ppg at the 9-5/8" shoe, and 13.0 ppg mud in the hole. DRilLING LINER SECTION: · · · · · ,J/""""-" ",/'" ~M6ío rs will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will ~~:ç.' ulated out as required. The drilling liner shoe will be drilled out with the 9.3 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Potential losses will be treated with the "Pay-zone" loss circulation decision tree. The well is planned to stop short of the OWC. The Kavik will not be penetrated. The project Geologist will be in charge of picking TD above the OWC and s~icient rathole will be drilled. The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TD. This scenario is based on a 9.45 ppg (0.5 ppg /1 over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. If the Sag River top comes in low, the well will be drilled horizontally to increase the area of pay drilled. PRODUCTION SECTION: · · · · · · 11 ) ) NS22 Permit to Drill NS22 Ria-site Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE -J Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS22 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. -J Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. -J Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any previously drilled Northstar wells. Mudloggers will be used continuously on NS22 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. -J Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 Y2" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. -J Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. -J Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. -J The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. -J Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. -J Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 12 õ I KB KOP Bid 1.5/100 Crv 2/100 Crv 2.5/100 Top Perm Base Perm Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: location latllong: location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: NS22 Proposed Well Profile - Geodetic Report November 11, 2002 Survey I DlS Computation Method: Minimum Curvature I Lubinski BP Exploration Alaska Vertical Section Azimuth: 25.750° Northstar dy Vertical Section Origin: N 0.000 ft, E 0.000 ft Northstar PF / NS22 . .ty Stll TVD Reference Datum: KB NS22 · b III TVD Reference Elevation: 56.1 ft relative to MSL NS22 Fea51 Sea Bed I Ground level Elevation: 15.670 ft relative to MSL 50029 Magnetic Declination: 26.086° NS22 (P20) S211 November 11, 2002 Total Field Strength: 57550.115 nT 45.232° /6150.00 ft 15.507 I 0.551 Magnetic Dip: 80.951 ° NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: January 16, 2003 N 70.49132358, W 148.69331433 Magnetic Declination Model: BGGM 2002 N 6031031.560 ftUS, E 659826.690 flUS North Reference: True North +1.23169393° Total Corr Mag North·> True North: +26.086° 0.99992902 local Coordinates Referenced To: Well Head Schlumberuer - Grid Coordinates Geographic Coordinates MD I Incl Azim TVD VSec I N/-S EI-W DlS Northing I Easting latitude I longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 6031031.56 659826.69 N 70.49132358 W 148.69331433 300.00 0.00 90.00 300.00 0.00 0.00 0.00 0.00 6031031.56 659826.69 N 70.49132358 W 148.69331433 400.00 1.50 90.00 399.99 0.57 0.00 1.31 1.50 6031031.59 659828.00 N 70.49132358 W 148.69330362 500.00 3.43 76.98 499.89 3.01 0.67 5.54 2.00 6031032.35 659832.21 N 70.49132541 W 148.69326905 600.00 5.41 73.40 599.59 8.07 2.70 12.97 2.00 6031034.54 659839.60 N 70.49133095 W 148.69320831 700.00 7.41 71.74 698.96 15.72 6.07 23.62 2.00 6031038.14 659850.17 N 70.49134016 W 148.69312126 800.00 9.40 70.78 797.88 25.98 10.77 37.45 2.00 6031043.13 659863.90 N 70.49135300 W 148.69300821 900.00 11 .40 70.15 896.23 38.81 16.82 54.46 2.00 6031049.55 659880.77 N 70.49136953 W 148.69286916 930.13 12.00 70.00 925.74 43.18 18.90 60.20 AOO 6031051.75 659886.47 N 70.49137521 W 148.69282224 1000.00 12.80 62.76 993.98 54.56 24.93 73.91 2.50 6031058.07 659900.04 N 70.49139168 W 148.69271017 ~ 1100.00 14.24 53.98 1091.22 74.24 37.23 93.71 2.50 6031070.79 659919.57 N 70.49142528 W 148.69254832 1200.00 15.93 46.91 1187.78 97.88 53.84 113.68 2.50 6031087.83 659939.18 N 70.49147066 W 148.69238508 1218.03 16.26 45.80 1205.10 102.56 57.29 117.29 2.50 6031091.35 659942.71 N 70.49148008 W 148.69235557 1300.00 17.81 41.24 1283.47 125.43 74.72 133.79 2.50 6031109.13 659958.83 N 70.49152770 W 148.69222069 1400.00 19.83 36.64 1378.13 156.83 99.84 154.00 2.50 6031134.68 659978.50 N 70.49159632 W 148.69205548 1500.00 21.94 32.89 1471.56 192.03 129.14 174.27 2.50 6031164.41 659998.13 N 70.49167636 W 148.69188978 1600.00 24.13 29.77 1563.58 230.96 162.58 194.56 2.50 6031198.27 660017.70 N 70.49176772 W 148.69172391 1612.64 24.40 29.41 1575.10 236.14 167.09 197.13 2.50 6031202.84 660020.17 N 70.49178004 W 148.69170290 Station ID NS22 (P20) report. xis Page 1 of 3 11/11/2002-2:44 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD I VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1700.00 26.36 27.14 1654.03 273.55 200.08 214.84 2.50 6031236.20 660037.16 N 70.49187016 W 148.69155813 1800.00 28.64 24.91 1742.73 319.71 241.58 235.07 2.50 6031278.12 660056.50 N 70.49198353 W 148.69139275 End Cry 1810.22 28.87 24.70 1751.68 324.63 246.04 237.13 2.50 6031282.62 660058.46 N 70.49199571 W 148.69137591 SV6 3316.92 28.87 24.70 3071.10 1052.04 907.03 541.09 0.00 6031949.94 660348.12 N 70.49380141 W 148.68889078 SV5 3627.53 28.87 24.70 3343.10 1201.99 1043.29 603.76 0.00 6032087.51 660407.84 N 70.49417364 W 148.68837835 13-3/8" Csg pt 3699.48 28.87 24.70 3406.10 1236.72 1074.86 618.27 0.00 6032119.38 660421.67 N 70.49425988 W 148.68825970 SV4 3981.54 28.87 24.70 3653.10 1372.90 1198.60 675.17 0.00 6032244.31 660475.89 N 70.49459790 W 148.68779443 SV2 4352.67 28.87 24.70 3978.10 1552.07 1361 .41 750.05 0.00 6032408.68 660547.25 N 70.49504266 W 148.68718211 SV1 4912.23 28.87 24.70 4468.10 1822.22 1606.89 862.93 0.00 6032656.51 660654.82 N 70.49571324 W 148.68625899 TMBK 5347.31 28.87 24.70 4849.10 2032.27 1797.76 950.71 0.00 6032849.21 660738.47 N 70.49623464 W 148.68554110 ---- WS1 7180.14 28.87 24.70 6454.10 2917.12 2601.82 1320.46 0.00 6033660.97 661090.83 N 70.49843107 W 148.68251677 CM3 7738.55 28.87 24.70 6943.10 3186.71 2846.79 1433.12 0.00 6033908.29 661198.19 N 70.49910024 W 148.68159515 Drp 2/100 9860.81 28.87 24.70 8801.56 4211.30 3777.83 1861.26 0.00 6034848.25 661606.18 N 70.50164345 W 148.67809216 Top HRZ 9896.96 29.60 24.70 8833.10 4228.95 3793.87 1868.64 2.00 6034864.44 661613.22 N 70.50168726 W 148.67803178 9900.00 29.66 24.70 8835.74 4230.46 3795.23 1869.27 2.00 6034865.81 661613.82 N 70.50169098 W 148.67802662 Base HRZ 9966.45 30.99 24.70 8893.10 4263.99 3825.71 1883.28 2.00 6034896.59 661627.17 N 70.50177423 W 148.67791198 10000.00 31.66 24.70 8921.76 4281.43 3841.56 1890.57 2.00 6034912.59 661634.12 N 70.50181753 W 148.67785232 Top Kuparuk 10036.96 32.40 24.70 8953.10 4301.03 3859.36 1898.76 2.00 6034930.56 661641.92 N 70.50186615 W 148.67778530 10100.00 33.66 24.70 9005.95 4335.38 3890.58 1913.12 2.00 6034962.08 661655.60 N 70.50195143 W 148.67766779 10200.00 35.66 24.70 9088.20 4392.23 3942.24 1936.87 2.00 6035014.23 661678.24 N 70.50209254 W 148.67747344 KupC 10285.72 37.37 24.70 9157.10 4443.23 3988.58 1958.19 2.00 6035061.02 661698.55 N 70.50221912 W 148.67729898 10300.00 37.66 24.70 9168.42 4451.92 3996.48 1961.82 2.00 6035068.99 661702.01 N 70.50224070 W 148.67726927 Fault Crossing 10386.50 39.39 24.70 9236.10 4505.79 4045.42 1984.33 2.00 6035118.40 661723.46 N 70.50237438 W 148.67708506 10400.00 39.66 24.70 9246.51 4514.37 4053.22 1987.92 2.00 6035126.28 661726.89 N 70.50239568 W 148.67705568 End Drp 10417.19 40.00 24.70 9259.71 4525.38 4063.22 1992.52 2.00 6035136.37 661731.27 N 70.50242300 W 148.67701804 TMLV 10502.55 40.00 24.70 9325.10 4580.24 4113.07 2015.45 0.00 6035186.70 661753.12 N 70.50255916 W 148.67683039 ~ 9-5/8" Csg Pt 10549.54 40.00 24.70 9361 .10 4610.44 4140.52 2028.07 0.00 6035214.41 661765.15 N 70.50263415 W 148.67672711 Kingak 11183.97 40.00 24.70 9847.10 5018.17 4511.01 2198.48 0.00 6035588.45 661927.54 N 70.50364614 W 148.67533246 Fault 49s1 Crossing 11584.73 40.00 24.70 10154.10 5275.74 4745.04 2306.12 0.00 6035824.72 662030.12 N 70.50428539 W 148.67445145 Target S21 12467.19 40.00 24.70 10830.10 5842.87 5260.38 2543.15 0.00 6036345.00 662256.00 N 70.50569301 W 148.67251122 Sag River 12489.38 40.00 24.70 10847.10 5857.13 5273.34 2549.11 0.00 6036358.09 662261.68 N 70.50572841 W 148.67246243 7" Csg pt 12533.76 40.00 24.70 10881 .1 0 5885.66 5299.26 2561.03 0.00 6036384.26 662273.04 N 70.50579921 W 148.67236485 Shublik 12631.67 40.00 24.70 10956.10 5948.58 5356.43 2587.33 0.00 6036441.97 662298.10 N 70.50595536 W 148.67214955 Top Ivishak 12749.15 40.00 24.70 11046.10 6024.09 5425.04 2618.89 0.00 6036511.24 662328.18 N 70.50614276 W 148.67189119 OWC 12892.74 40.00 24.70 11156.09 6116.36 5508.89 2657.45 0.00 6036595.89 662364.92 N 70.50637179 W 148.67157551 NS22 (P20) report.xls Page 2 of 3 11/11/2002-2:44 PM I TD 14-1/2" Lnr Pt Station ID LeQal Description: MD (ft) 12892.75 Incl (0) 40.00 Azim TVD (0) (ft) 24.70 11156.10 Surface: 1259 FSL 646 FEL S11 T13N R13E UM Target S21: 1238 FSL 3379 FEL S1 T13N R13E UM BHL: 1487 FSL 3265 FEL S1 T13N R13E UM NS22 (P20) report. xis VSec (ft) 6116.37 Nt-S (ft) 5508.90 NorthinQ ey) rftUSl 6031031.56 6036345.00 6036595.90 Page 3 of 3 EI-W (ft) 2657.46 DLS (0/100ft) 0.00 EastinQ eX) rftUSl 659826.69 662256.00 662364.93 Geographic Coordinates Latitude I Longitude Grid Coordinates Northing Easting (ftUS) (ftUS) 6036595.90 662364.93 N 70.50637182 W 148.67157543 -~ .--- 11/11/2002-2:44 PM ) ) 0"':.'.."".""':'.".':':,'.,"::."""".b,..:",.,.,..,,.,.,p .'" ",,'1, 'I, I', .,1 VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS22 (P20) Field: Northstar Structure: Northstar PF Section At: 25.75 deg Date: November 11, 2002 Schlumbørger o - -------1 ~~I~~1f J~~~t: __ ~ __ ~ ,-. ,J~"'g~~-1jJ~~º.~ªqJy.IL,-T--- -.----,-. --,.,-------+ - Fauii49s1Crœsing1158s Mõ if54TVD- - - - - ~ : I Hold Angl~ 40.00° ~~~~~~BW171\l¡¡:: 7J1f}J 1~3~"W1~~ 400 TVD 1.50' 9J.00' az 1 departJre Cry 2.51100 930 MD 926 TVD - croO'-70:OO' ãZ 43 departure End Crv :p~m=21~D=20~TV5 = Base Perm 1613 MD 1575 TVD> 2000 _. 325 departure 13-318" Csg PI 3699 MD 3406 TVD / 28.87' 24,70' az _ /- _ ..223~de~rtu~ _ šii6 3317MD 3071TVD šii5 3628MD 3343TVD šii4 3ge2MD 3653TVD - .- 0>- .æ~ 8:2 o 0> C\I > II ~ [: CO ;:~ _0 .r.~ ã.~ 0>- om -~ ~.¡...: t 0> O>~ > ã> ~jjJ ~ I- 4000 _. "§V'2~5~"t1C¡~7nvl3""' šii1 4rJ12MD 4468TVD TMBK5347 MD 4849 TVõ Hold Angle 28.87° 6000 - r171ŠÕMD6454 TŸÕ tsM37739MD6s43 T\ÎÕ - Dr"p 21100 - - - 9861 MD 8802 TVD _ 2a.87::""24.ZP' IIZ. _ 4211 departure 8000 - End Drp 10417 MD 9260 TVD 40.00' 24.70' az 4525 departure ¡:: f 9 1 0000 ~ r I I -, --¡ Target 521 ï 12467 MD 108:~ITVD ~-=~~:" 7" Csg PI I 12534 MD 10881 TVD = 4ii:OOC24:ZÕ' ~ = 5!B6 dePaãiire = 12000 - TD , 4-112" Lnr PI 12893 MD 11156 TVD 40,00' 24,70' az 6116 departu,e'- -2000 I o I 2000 I 4000 I 6000 I 8000 Vertical Section Departure at 25.75 deg from (0.0, 0.0). (1 in = 2000 feet) O·······bP ,'.............,..........'. ..:' . " :' ; :,: ~ " , ' I 6000 -. 5000 - ~ 4000 -.. ^ I I- 0:: o Z 3000 - I 2000- I- :J o en v v v 1000 - 0-..' ) ) PLAN VIEW Client: BP Exploration Alaska Well: NS22 (P20) Field: Northstar Structure: Northstar PF Scale: Date: 1 in = 1000 ft l1-Nov-2002 Schlumberger -1000 , 1000 , 3000 , True North Mag Dee ( E 26.09° ~ ....·,",'..·.·.".·.".'",,·.···.....··.·.,,·1..·-"'·,. ...·,·..1· :k P"""'""""~"" :S ::5' .S' ~ .þ :B 13-3/8" Csg pt 3699 MD 3406 TVD 28,87" 24,70' az 1075 N 618 E Cry 2/100 400 MD 400 TVD 1,50· 9000· az ~ ON 1E ~ . -~OP B,~1.~1~..7 300 MD 300 TVD 0,00· 90,00· az ON 0 E ~ EndCrv ....., ,----.. -..,-, -18fó'MD~175:2'TVD ----'",--, 28,87' 24.70' az 246 N 237 E Cry 2.~100 930 MD 926 TVD 12.00' 70,00· az 19 N 60 E I -1000 I o «< WEST I 1000 2000 , 7" Csg PI 12534 MD 10881 TVD 40.00·, 24.70· az 5299 N 2561 E Target 521 12467 MD 10830 TVD 40,00· 24,70· az 5260 N 2543 E 9861 MD 8802 TVD .. ""'2ifâiõ'24,iÖõa:Z"" ".. 3778 N 1861 E .. '-'"---"--'-_."'-'-~" .-----...---,. -,,~, .--- I 2000 EAST »> I 3000 - 6000 5000 ........ --4000 . ·,·--,-3000 - 2000 - 1000 ...-n_O ) Schlumberger Anticollision Report ) Company:' BPAm~co Field: N()~h:,;t¡;¡r Reference Site: NorthstarPF Reference ",eU: NS22 ; RefereµceWellpåth: PlanNS22 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 39.87 to 12892.75 ft Maximum Radius: 3000.00 ft I ~,," I Qa~~ 11{11l20ß?'i TimèL ',1'S:()5:50 ~~U:N~22,,'.True·..No~h N33E55.8 çQ~rdil1~t~(N~)..·Refer~n~e: " Vet1i~1iI(t"»).~efe~e~ce: Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 6/27/2002 Validated: No Planned From To Survey ft ft 39.87 1000.00 Planned: Plan #20 V1 1000.00 12892.75 Planned: Plan #20 V1 Version: 8 Toolcode Tool Name GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points MD TVD Diameter Hole Siz~ ft ft in in 3699.10 3405.77 13.375 16.000 13 3/8" 1 0549.11 9360.77 9.625 12.250 95/8" 12533.33 10880.77 7.000 8.500 7" 12892.75 11156.10 4.500 6.125 41/2" Summary <-..;...----- Qffset Wellpatl1 Reference Offset ctl':Ctr' ..l'lo~Go Allowable Site Well MD MD ¡ "', J)istance Area " Deviation Warning ft. ff ft ,ft ft I Northstar PF NS05 Plan NS05 V10 Plan: PI 546.57 550.00 171.42 11.39 160.04 Pass: Major Risk ../ Northstar PF NS06 NS06 V32 498.03 500.00 162.03 8.63 153.40 Pass: Major Risk Northstar PF NS07 NS07 V33 149.64 150.00 151.39 3.12 148.27 Pass: Major Risk Northstar PF NS08 NS08 V18 349.83 350.00 140.67 6.27 134.41 Pass: Major Risk Northstar PF NS09 NS09 V14 546.96 550.00 134.57 8.72 125.87 Pass: Major Risk Northstar PF NS10 NS10 V17 596.61 600.00 111.17 9.00 102.30 Pass: Major Risk Northstar PF NS12 NS12 V23 399.35 400.00 94.92 7.55 87.37 Pass: Major Risk Northstar PF NS13 NS13 V12 498.41 500.00 93.42 8.30 85.13 Pass: Major Risk Northstar PF NS14 NS14 V11 598.49 600.00 77.38 10.23 67.14 Pass: Major Risk Northstar PF NS15 NS15 V19 449.15 450.00 71.62 7.83 63.80 Pass: Major Risk Northstar PF NS16 NS16 V34 448.63 450.00 60.51 8.98 51.54 Pass: Major Risk Northstar PF NS17 NS17 V10 500.00 500.00 52.70 7.73 44.99 Pass: Major Risk Northstar PF NS18 NS18V11 449.49 450.00 38.48 8.83 29.65 Pass: Major Risk Northstar PF NS19 NS19 V9 550.49 550.00 30.63 9.66 20.97 Pass: Major Risk Northstar PF NS20 NS20 V10 500.00 500.00 20.62 7.96 12.70 Pass: Major Risk Northstar PF NS21 Plan NS21 V43 Plan: PI 599.60 600.00 11.87 10.35 1.52 Pass: Major Risk Northstar PF NS23 Plan NS23 V26 Plan: PI 399.95 400.00 10.88 7.45 3.43 Pass: Major Risk Northstar PF NS24 NS24 V14 649.54 650.00 21.00 10.82 10.20 Pass: Major Risk Northstar PF NS26 NS26 V22 600.57 600.00 38.53 9.79 28.78 Pass: Major Risk Northstar PF NS27 NS27 V29 948.46 950.00 46.45 17.09 29.53 Pass: Major Risk Northstar PF NS29 NS29 V22 349.55 350.00 69.99 6.32 63.67 Pass: Major Risk Northstar PF NS31 NS31 V14 1152.05 1150.00 83.47 20.24 63.40 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 1692.57 1650.00 209.71 33.64 176.33 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 1638.29 1600.00 224.40 32.17 192.45 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 1687.08 1650.00 214.73 29.15 185.95 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1809.79 1750.00 207.10 37.05 170.37 Pass: Major Risk ') ) Schlumberger Anticollision Report CO'Ppany: Field: Reference~ite: Reference Well: Refer¢ßceWellpath: BPArnoco North$tår Northstar PF NS22 Plan NS22 Date: 11/11/2002 Time: 't5:07:22 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 39.87 to 12892.75 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Wet.l: NS22,TrueNorth N33E55.8 ()b:, Syb~se Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing . ~~~'r~lnªte(NE)~!ference: Verticål~. (TVD)··Reference: Survey Program for Definitive Wellpath Date: 6/27/2002 Validated: No Planned From To Survey ft ft 39.87 1000.00 Planned: Plan #20 V1 1000.00 12892.75 Planned: Plan #20 V1 Version: 8 Toolcode Tool Name GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points MD TVD , Diameter Hole Size ft ft I in in 3699.10 3405.77 13.375 16.000 13 3/8" 1 0549.11 9360.77 9.625 12.250 95/8" 12533.33 10880.77 7.000 8.500 7" 12892.75 11156.10 4.500 6.125 4 1/2" Summary <-... - -_...._-~ Offset Wellpatll -..;....~ Refe~e~ce Offset .., çtr.~ÇtrNo-C:;() A~lo\V~ble Site Well Wellpath MD '··'·1\10 Distance.. Area Deviation warning ft it ft ft ft Northstar PF NS05 Plan NS05 V1 0 Plan: PI 546.57 550.00 171.42 11.39 160.04 Pass: Major Risk Northstar PF NS06 NS06 V32 498.03 500.00 162.03 8.63 153.40 Pass: Major Risk Northstar PF NS07 NS07 V33 149.64 150.00 151.39 3.12 148.27 Pass: Major Risk Northstar PF NS08 NS08 V18 349.83 350.00 140.67 6.27 134.41 Pass: Major Risk Northstar PF NS09 NS09 V14 546.96 550.00 134.57 8.72 125.87 Pass: Major Risk Northstar PF NS10 NS10 V17 596.61 600.00 111.17 9.00 102.30 Pass: Major Risk Northstar PF NS12 NS12 V23 399.35 400.00 94.92 7.55 87.37 Pass: Major Risk Northstar PF NS13 NS13 V12 498.41 500.00 93.42 8.30 85.13 Pass: Major Risk Northstar PF NS14 NS14 V11 598.49 600.00 77.38 10.23 67.14 Pass: Major Risk Northstar PF NS15 NS15 V19 449.15 450.00 71.62 7.83 63.80 Pass: Major Risk Northstar PF NS16 NS16 V34 448.63 450.00 60.51 8.98 51.54 Pass: Major Risk Northstar PF NS17 NS17 V10 500.00 500.00 52.70 7.73 44.99 Pass: Major Risk Northstar PF NS18 NS 18 V11 449.49 450.00 38.48 8.83 29.65 Pass: Major Risk Northstar PF NS19 NS 19 V9 550.49 550.00 30.63 9.66 20.97 Pass: Major Risk Northstar PF NS20 NS20 V1 0 500.00 500.00 20.62 7.96 12.70 Pass: Major Risk / Northstar PF NS21 Plan NS21 V43 Plan: PI 400.01 400.00 10.10 3.34 6.77 Pass: Minor 1/200 Northstar PF NS23 Plan NS23 V26 Plan: PI 349.99 350.00 10.20 3.10 7.10 Pass: Minor 1/200 Northstar PF NS24 NS24 V14 649.54 650.00 21.00 10.82 10.20 Pass: Major Risk Northstar PF NS26 NS26 V22 600.57 600.00 38.53 9.79 28.78 Pass: Major Risk Northstar PF NS27 NS27 V29 948.46 950.00 46.45 17.09 29.53 Pass: Major Risk Northstar PF NS29 NS29 V22 349.55 350.00 69.99 6.32 63.67 Pass: Major Risk Northstar PF NS31 NS31 V14 1152.05 1150.00 83.47 20.24 63.40 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 1692.57 1650.00 209.71 33.64 176.33 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 1638.29 1600.00 224.40 32.17 192.45 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 1687.08 1650.00 214.73 29.15 185.95 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1809.79 1750.00 207.10 37.05 170.37 Pass: Major Risk Field: Site: Well: Wellpath: Northstar Northstar PF NS22 Plan NS22 "-' '~ T~ c)tÎŒlft' _.uœ'IIÙI (TfO+AZl) I*ù n Q-oIn to Ctntn Sepantioo [6OftJip Site: Northstar PF ) DriIling Target Cont:: 99'1_ Description: Map Northing: 6036345.00 ft Map Easting : 662256.00 ft Latitude: 70030'20.495N Shape: Circle Target: 821 }ell: NS22 Based on: Planned Program Vertical Depth: 10774.00 ft below Mean Sea Level Local +N/-S: 5260.37 ft Local +E/-W: 2543.15 ft Longitude: 148°40'21.040W Radius: 300 ft 0 5100 5500 5500 54-00 N ^ 5300 5200 5100 5000 4-900 4-800 ~ D D D D D D D D D D D D D D D D D D D D ~ 0 N (Y) J Ln LO r- CD a- D / N N N N N N N N (Y) (Y) ~ ~ / ~ ~ / ~ / / WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) '\ } ORIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.9' NS22 / Operation Shutdown .. 6.8PPG DIESEL FREEZE PROTECTION AT +1- 200' TVD (200'MD) 9.4 ppg Seawater from 200' MD I 200' TVD to 3699' MD I 3406' TVD .. 13 3/8", 68#/ft, L-80, BTC @ 3699' MD ~ .. EMW = 8.95 ppg DATE REV. BY COMMENTS 11/18/02 BMH ~S22 Operation Shutdown Northstar WELl: NS22 AP I NO: BP Exploration (Alaska) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8' Multibowl 5ksi ) NS22 - Proposed / 13 3/8", 68#/ft, L-80, BTC @ 3699' MD 3 1/2", 9.2#/ft, 13-Cr, Yam-Ace TUBING 10: 2.867" CAPACITY: 0.0087 BBLlFT 9-5/8" 47# L-80 BTM-C @ 10550' MD 3.5" X NIPPLE, @ 12334' MD 3.5" X NIPPLE, @ 12354' MD 3.5" XN NIPPLE, @ 12364' MD 3.5" WLEG, @ 12374' MD 7", 26#/ft L-80, Hydril 521 @ 12534' MD ) PBTD @ 12813' MD TO @ 12893' MD ~ ~ ~ 6 !J , E J, j DATE REV. BY COMMENTS 11/18/02 BMH NS22 Proposed .. \>RIGINAL KB. ELEV = 56' ,~B-BF. ELEV = 40.1' CB. ELEV = 15.9' 3 1/2" SSSV @ 1000' TVD wI HXO SVLN nipple 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (7253'MD) ~ 3 1/2" GLM @ 4500' TVD (4949' MD) 3 1/2" GLM @ 5866' TVD (6500'MD) ~ 7" LINER TOP @ 10400' MD V I 3.5" Fiber Optic Transducer -;;- _ 7" PACKER,13 Cr @ 12344' MD I I r~ ~ 4.5" LINER TOP @ 12384' MD ... .. 4.5",12.6#, 13CrVam Ace Northstar WELL: NS22 API NO: BP Exploration (Alaska) NS22 Drilling Permit ) Subject: NS22 Drilling Permit Date: Tue, 19 Nov 2002 18:44:30 -0600 From: "Hernandez, Floyd" <HernanF1@BP.com> To: "'Winton Aubert' (E-mail)..<Winton_Aubert@admin.state.ak.us> Winton, Appreciate your help in accelerating the permit approval process for well NS22. The reason for the late submittal is due to the lack of the required ice thickness (18") to lift the Seasonal Drilling Restrictions (SDR). Original plans were to startup batch completions on the suspended wells as soon as the SDR was lifted which was anticipated to be Nov 15th. The original plan also had a contingency plan to drill the NS21 surface hole just in case the ice thickness was not 18" by Nov 15th. On Nov 15th the ice thickness was measured at 15", so the NS21 contingency plan went into effect. Weather forecast at the time gave all indications that the 18" ice thickness requirement would be met by the time the NS21 surface hole was drilled and completed. As of today, the ice thickness measured 16". We currently anticipate moving off of NS21 on Thursday, Nov. 21st. Our preference would be to move to NS24 to startup the batch completion mode, however the ice thickness requirement of 18" may not allow for moving to NS24. So instead of placing the rig on standby, we have elected to quickly submit a request to drill the NS22 surface hole while waiting on the 18" ice thickness requirement If you have any questions, please give me a call at 564-5960 Thanks, Floyd Hernandez Senior Drilling Engineer Northstar Development (907) 564-5960 work (907) 240-8056 cell hernanf1@bp.com M inerals ··Managel!'entServic;~.. \ .fNlS) ··w~t.þ().~e ÇOPy¡rpél~~~¡~'~tJ~~.i~~"'f~9~,~~i9~P:,:,>"qMI3App{()vall:Xpirøs.1.0/311200f ·"'ÂPÞI·iøáH()n.i'ª~:ipøt..n"i·f;;£~·:::!Î·~ill:,.::{~~:~.îi:i;····· ...... '. 1. PROPOSALTO DRILL '2.MMSOPERATO~N()~: :3.()F'E~TOR~AME~nd~D[)~E......·. S. S , ., (Sûbn1lttin office) .y: ~NEWW.ELL DSIDETRACK 0 BYPASS. 0 DEEPEN 00t13 .. .'. .... g.,. . 4. WELL NAME (Current) 5. SIDETRACK NO. (Cürrel1t)6.BYPASS~().(Cutrent) ~PE)(pl?rationAJask~,ll1t. NS22 N/A N/AP·9·<B()x1~~612 Anchorage, At< . ~9519-661ª 7. PROPOSED START DATE November 21, 2002 8. PLAN CONTROL NO. (NewWeIlOnlÿ) 9. API WELL' NO. (Current Sidetråck I Bypass) (12 DigIts)) N/A WELL AT TOTAL DEPTH (PROPOSED) 10. LEASE NO. WELL AT SURFACE OCS-Y0181 15. LEAsE ~(); . 11. AREA NAME Beechey Point 12.BLOCKNO. 17. BLOCK NO. 13. LATITUDE gI NAD 27 (GOM & Pacific) o NAD 83 (Alaska) 516 14. LONGITUDE ~ NAD 27 (GOM& Pacific) o NAD 83 (Alaskå) 18. LATITUDE ~ ..... NAD2.7(GO~i&·,paCific) ..... o NAP 83 (Alaska) 515 19..LONGITUDE ~.N~D27(GOM & Pacific) DNA[) 83 (Alaska) Top of Kuparuk LIST OF SIGNIFICANT MARKERS ANTICIPATED 21. TOP.' (MD) 20. NAME 10037' 21. TOP (MD) 20. NAME Top of Sag River 12489' 22. LIST ALL ATTACHMENTS (Attach Complete Well Prognosis and Attachments Required by 30 CFR 250.41!:.J.P. .'. D-... ". iI;,' D· 30 CFR 250.1617 (C) and (D), As Appropriate) ~ :f.~ '".' ~ NS22 Well Plan, NS22 Directional Survey, NS22 AOGCC Permit Application anda Supplemental APD Inforr ...ft'. '. ~-'õrm (MMS-123S. 23. AUTHORIZING OFFICIAL (Type or Print Name) Floyd Hernandez 25. AUTHORIZING~IGNA:~y 24. TITLE NOV 1 9 :2002 A1ab1\a 011·& Goo GonL Commission . Anchorage Senior Drilling Engineer 26. DATE \l/\9/0<- THIS SPACE FOR MMS USE ONL Y --ÄPPRÕVËÕ~-----------------~BY---------------------------------~TITiE------------------------------ I I o With Attached Conditions : : _____~_~~~~~~~~~~i~~~________~___________________________________~---------------------------------- API WELL NO. ASSIGNED TO THIS WELL : DATE I PAPERWORK REDUCllON ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 ~ Requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor. and a person is not required to respond to. a cotlection of information unless it displays a currently valid OMS Control Number. Public reporting burden for this form is estimated to average 2% hours per response, induding the time for reviewing instructions. gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230. Minerals Management Service, 1849 C Street, NW., Washington, DC 20240. MMS FORM MMS-123 (October 2002 - Supersedes all previous versions of form MMS-123 which may not be used.) Page 1 of 1 u.s. Department of the Interior Minerals Management Service (MMS) Submit ORIGINAL plus TWO copies with ONE copy marked "Public Information. OMB Control Number 1010-0131 OMB Approval Expires 10/3112005 ,.S\lpplementaIAPDJnformation Sheet 1. OPERATOR NAME BP EXPLORATION ALASKA, INC. 2. API WELL NO. (Proposed) (12 Digits) 5. WELL NAME (Proposed) NS22 6. TYPE OF WELL o EXPLORATORY IKI DEVELOPMENT 8. BYPASS NO. (Proposed) N/A 11. WATER DEPTH 40' 12. ELEVATION AT KB Planned KBE=55.77' 3. BOTTOM LEASE NO. (Proposed) OCS-Y0181 7. SIDETRACK NO. (Proposed) N/A 13. H;æS DESIGNATION o KNO~ 0 UNKNOVVN ~ ABSENT 4. TOTAL DEPTH (Proposed) r-,MD 12893' 9. RIG NAME 10. RIG TYPE 14. H;¡S ACTIVATION PLAN DEPTH FT (TVD) TVD 11156' NABORS 33E 15. ENGINEERING DATA ROTARY N/A Casing Depth Rated BOP (Feet) WoriOng Tnt PrMlUr.. Drißing Hole Weight Burst Rating Safety FadOf$ Top of Casing Shoe Pressure Fluid Type Casil"(¡ Ca&il"(¡ (1IIFeet) (pai) MASP Uner (ppg) WeII-head Annularl Annularl Size (Indic<lte if Size Type of MD RaUng BOP Size Diverter Diverter Cn/I"(¡ T..t Cement (01 B.... (IN) Liner) (IN) Connection {fW] (In) (pal) Cajng (Feer) Water (pal] (pal) (pal) Shoe Baso. Grade Cotlapae RIÜI"(¡ TVD PP MW FG Ram Ram MW lJMd for (ppg) Synthl)/ÍC) (pal] (pal] (pIi) Tnt (ppg) Drivel 5tru<:Iural 20" 169# 3910 201' CondUåor 20" WELD 0 DRIVEN X-56 2500 201' 68# 5020 3699' 5000 3500 3500 16" Surface 13-3/8· BTC 1110 1.36 3.47 3.32 8.65 9.5 13 5000 13-5/8" 11 WATER BASE L-80 2270 3406' 5000 5000 9.3 47# 6870 10550' 5000 3500 4100 12-114" In_Ie 9-5/8" BTC-M 3336 1.54 1.76 1.94 9.26 10.5 15 5000 13-5/8" 12.8 WATER BAS L-80 4760 9361' 5000 5000 10.3 26# 7240 12534' 5000 3500 3555 8-1/2" DriIõ>g üner 7" 3753 1.42 1.42 3.57 10400' 8.95 12.5 15.3 5000 13-5/8" 11.5 WATER BAS L-80 5410 10881' 5000 5000 9.1 12.6# 6840 12893' 5000 3500 3750 .ß-.1!8" -..,. 4-1/2" VAMACE 3848 1.83 1.33 2.44 12384' 8.95 9.3 15.3 5000 13-5/8" WATER BAS 13Cr 7500 11156' 5000 5000 8.65 _. CONTACT NAME 17. CONTACT PHONE NO. 18. CONTACT E-MAIL ADDRESS Barbara M. Holt 1 Floyd Hernandez Barb - 564-5791 1 Floyd - 564-5960 HoltBM@BP.com 1 HernanFL@BP.com 19. Will you maintain quantities of mud and mud material (including weight materials and additives) sufficient to raise the entire system mud weight Y, ppg or more? KJ YES 0 NO 20. REMARKS: Safety Factors are from Northstar Casing Basis of Design PAPERWORK REDUCTION ACT OF 18eS (PM) STATEMENT: The PM (44 U.S.C. 3501 §1ØS!, requires us to inform you that we collect this information to obtain well sIatu$. well and casing test, and well casil"(¡ configuration date. MMS uses thif information to have accurate data and Information on al wellt under its juri!idietion and to ensure compianœ -Mth approved pia,.,.. ResponMS are mandatory (43 U.S.C. 1334). Proprietary datil are covered under 30 CFR 250.196. M agen<:y may not condUå or llpon&or, and a person if not required to respond to. a coIedion of Information unlellll I difplays a c;urrently valid OMB Control Number. Public repoltil"(¡ burden for this form '- estimated to average 1% hour per reaponse, including the lime for reviewil"(¡ instructions, gatheril"(¡ and maintaining data. and completing and reviewing tile form, Direct comments regarding the burden estimate or any other aspect of this form to the Information Cotleàion Clearance OffICer, Mail Stop 4230. Miner.1t Management Service. 1849 C Street. NW.. Washi'IgIon. DC 20240. MM$' · FORMMMS-123S(OctOber 2002 -Superséd~alIPrevioU~'versior1sof forrnMM5-123S which maynot be used.) Page 1 of 1 ) ') bp .,. ,~'.'ii1I. -.......~ ~....- ~..,- ~...-- .....~ ~... ·'I'~~§\" .,. BP Exploration Alaska Inc. To: Kyle Monkelien - MMS Date: November 18,2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS22 Application for Drilling Permit Mr. Monkelien, Well NS22 is currently scheduled for Nabors 33E on November 215\ 2002. The NS22 well path intersects the Area of Review for a proposed disposal well NS32, much the same circumstance as well NS07 and the NS10 Area of Review. Well NS32 has not been drilled; however, a proposed well path exists. The EPA permit for NS10 Area of Review states "New wells within the area of review shall be constructed in accordance with the AOGCC Regulations Title 20-Chapter 25. Further, all wells in the Area of Review shall have casing cemented to the formation throughout the entire section from the base of the lower confining zone to the top of the upper confining zone". Though NS32 is not yet drilled, this EPA permit will be followed in case the NS32 well is drilled. There fore, cement will be brought from the 9 5/8" casing shoe to the top of the SV6 confining shale. This formation top is located inside the 13 3/8" casing. In order to both cement and freeze protect this annulus, a down-squeeze must be performed. It is requested the 13 3/8" casing seat be located at 3,699' MD/3,406'TVD in the SV5 (rather than in the SV6 shale). This will increase the certainty of which formation will break down (SV5 sand) during the down squeeze, thus increasing certainty in formation coverage. Excessive gas is not an issue in this shallow sand. The maximum amount of gas found in the SV5 since BP Northstar drilling began has been 45 units. A Diverter waiver is requested on NS22. To date, BP has drilled nineteen development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Eighteen surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (-150' TVD below the top of the SV6), with one well extending into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. NS22 will perform an "Operation Shutdown" during the 2002 Seasonal Drilling Restriction period. A Sundry for the Operation Shutdown will be submitted minimum of ten days prior to shutdown operations. Please find attached the NS22 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5791. p7fl~ Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 ) ') NS22 SUMMARY DRilLING OPERATIONS Pre-RiQ Work: 1. Set 20" conductor and weld an ABS Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) RiQ Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A 07 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-60' TVD below the top of the SV5 marker at approximately 3628' MD. Surface casing point has been picked at 3699' MD. POOH. 4. Run 13-3/8",68# surface casing. Cement the casing to surface in 1 stage. No TAM port collar will be run. The risk of leak, and potential loss of hole, far outweighs the likelihood of not getting cement to surface in one stage. 5. Displace cement with 9.4 ppg brine. Bump plug and hold 500 psi for casing integrity. RIH with drill pipe with closed TIW valve to displace 200' MD (-30 bbls) of seawater. POOH. 6. ND diverter / riser system and NU casing / multi-bowl wellhead. 7. RU truck to pump diesel freeze protect. 8. Shut down and monitor the well for a minimum of 30 minutes. POOH 9. Prepare for UOperations Shutdown. (June 1st Seasonal Drilling Restriction)" 10. Install 4 %" tubing hanger and test to 500 psi. 11. Set the TWC. NU Tree. Test the tubing head adapter and tree to 500 psi. 12. Install (dry rod in) BPV and test. Ensure all valves are closed. RD and move off well. 13. Prepare to re-enter well post uSeasonal Drilling Restriction. " 14. MIRU Nabors 33E. 15. Pull BPV. Install TWC. ND dry hole tree. NU BOPE and test to 250/4800 psi. 16. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 17. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a minimum of 11.0 ppg EMW. (FIT/LOT procedure on file with AOGCC). 18. Drill 12-1/4" intermediate hole to casing point (approximately 10,550' MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.3 ppg at the top of Kuparuk. POOH. (No logs will be run, unless the Kuparuk is oil bearing.) 19. Run 9-5/8", 47# intermediate casing. Cement the casing to the top of the SV6 confining shale in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with no more than 1 annular volume of mud upon installing and testing the packoff. 20. Down-squeeze cement sufficient to cover the SV6 shale, followed by a spacer and diesel to 2000' TVD for freeze-protection. W OC. 21. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4100 psi with 10.3 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 22. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a minimum of 12.8 ppg EMW, (FIT/LOT procedure on file with AOGCC). 23. Weight up to minimum 12.5 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sa'g at approximately 12,489' MD. Intermediate casing point has been picked at 12,534' MD. POOH. NS22 Permit to Drill ) ) 24. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 25. POOH and lay down liner running tools. Test 9 5/8" x 7" liner lap to 2000 psi for 30 minutes with 12.8 ppg fluid (or 3555 psi with 9.1 ppg fluid). 26. RIH wi 6-1/8" directional assembly. Displace to 9.1 ppg mud. Clean out 7' liner to the landing collar. 27. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 28. Drill 6-1/8" production interval to the proposed TO at 12,893' MD. Increase mud weight to 9.3 ppg prior to POOH. 29. Make a clean out run, if required, and condition the hole for a liner. POOH. 30. Run and cement the 4-112" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate a minimum of 1 (one) bottoms up to remove excess cement with 9.3 ppg viscosified brine. . In the event the Sag River tops comes in deep, the well will be drilled as a horizontal, completed with a 4 %" 12.6# 13Cr slotted liner. A Sundry will be submitted at that time. 31. Circulate to clean seawater (less than 80 NTU's) using spacers as per Baroid recommendation. 32. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 33. POOH. Close the blind rams and pressure-test the liner lap to 3750 psi with 8.65 ppg seawater in the well for 30 minutes. Prepare to run the 3 %" 9.2# 13Cr completion. No slick line work will be done. 34. Run the 3 %", 9.2# 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 35. RIH to packer setting depth. The TRM-4E Camco SSSV control lines will be run from the TRSV at +1- 1000' TVD to surface. 36. Run space out pups and terminate the 0.25" control line and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function- test the fiber optic line. 37. Pump corrosion inhibitor and heated diesel down the 3 %" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4387' MD). RU the U-tubing manifold. 38. Drop ball and rod to set packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 39. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 40. Bleed down the annulus to 0 psi. Bleed down the tubing to 0 psi. 41. As we have had difficulty with the RP shear valve, it is essential the pressure sequence be followed. Pressure up the annulus to 2500 psi. This will shear the RP valve in the lower most GLM. 42. Bleed off annulus to 0 psi. 43. Allow fluids to U-tube from the annulus into the tubing through the lower GLM, -6500' MD. 44. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 45. Install and test (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: November 21m, 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 2 NS22 Permit to Drill ) ) NS22 WELL PLAN SUMMARY I Type of Well (producer or injector): 1 Producer NS22 1259'FSL,646'FEL,Sec.11,T13N,R13E,UM X = 659827 Y = 6031032 1238' FSL, 3379' FEL, Sec. 1, T13N, R13E, UM X = 662256 Y = 6036345 10,830' TVDrkb 1487' FSL, 3265' FEL, Sec. 1, T13N, R13E, UM X = 662365 Y = 6036596 11,156' TVDrkb 1 AFE Number: 1831326 1 Rig: I Nabors 33E 1 1 Estimated Start Date: 111/21/02 1 Operating days to complete: 131.8 I 1 MD: 112,893 I I TVDrkb: 111,156 I 1 RKB/Surface Elevation: (a.m.s.l.) 156.0' /15.9' I I Well Design (conventional, slim hole, etc.): I Modified Big Bore I I Objective: I Ivishak Producer with fiber optic surveillance control line I Northstar Slot: Surface location: Target (top of SAG): 300' Radius Bottom Hole location: Well Name: API Number: _ Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS22 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 OF @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20",169#, X-56 (pre-driven) 3 NS22 Permit to Drill ) MUD PROGRAM: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3699' MD /3406' TVD (-60' TVD below top SV5). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec Initial 8.8-9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 >6 15 - 25 6 -10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 - 100 20 - 35 >6 10 - 25 6-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer From Surface Casing Shoe to 10,550' MD /9361' TVD. Interval Density (ppg) PV Initial 8.7 - 9.3 10 -16 Top HRZ 10.3 10 - 16 Top Kuparuk to Miluveach 10.3 10- 18 12-1/4" Hole Section YP 20 - 30 20 - 25 20 - 28 Tauo API/ HTTP FL 4-7 6-10 4 - 7 4-6 / < 12 4-7 4-6/<12 pH 8.5 - 9.5 8.5 -9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 9" Hole Section From Intermediate Casing Shoe to 12,534' MD /10,881' TVD (top of Sag) Interval Density (ppg) PV YP Tauo Miluveach & Kingak to top of Sag 12.5 - 13.0 25 - 30 20 - 30 4 - 8 APIFL 4-6/ <10 pH 8.5 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 12,893' MD /11,156' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 8 -12 20 - 25 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P20) KOP: Maximum Hole Angle: Close Approach Wells: Survey Program: ±300' MD Cantenary curve 1.50°/100' to 2.50°/100' build ±40.00° Surface- 10' well spacing to well NS21; NS20 is 1.52' at 600' MD (major risk). Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1000'. Standard MWD surveys from +/-1000' to TD. IFR will not be utilized. SURFACE AND ANTI-COLLISION ISSUES: All wells pass the major risk rule. Gyros will be run from surface to -1000' MD or until reliable MWD surveys can be taken. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 4 NS22 Permit to Drill ) ) LOGGING PROGRAM: 16" Section: Drilling: GRlDirectional - Gyro as needed to -1000' MD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GRlDirectional, Resistivity (real-time), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 9" Section: Drilling: GRlDirectional, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GRlDirectional, Resistivity/Density/Neutron (recorded) Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None Inteç¡rity TestinQ: Test Point Depth Shoe Test Type FIT FIT FIT EMW Estimated Casing/Liner Test 3500 psi w/ 9.3 ppg 4100 psi w/ 10.3 ppg 3555 psi w/ 9.1 ppg 3750 psi w/ 8.65 ppg 13 3/8" Surface 95/8" Intermediate 7" Drilling Liner 4 Y2" Production Liner 20' min from 12 1/4" shoe 20' min from 95/8" shoe 20' min from 7" shoe 11.0 ppg EMW Target 12.8 ppg EMW Target 11.5 ppg EMW Target CASINGITUBING PROGRAM: Hole Size Casing/ Wt/Ft Grade Conn. Casing Casing Top Hole 8tm Tbg O.D. Length MDITVDrkb M DITVDrkb 20" 20" 169# X-56 WELD 201' Surface 201 '/201' 16" 13 3/8" 68# L-80 BTC 3699' Surface 3699'/3406' 12 X" 9 5/8" 47# L-80 BTC-Mod 10550' Surface 10550'/9361' 8 Y2" 7" 26# L-80 Hydril 521 2134' 10400'/9247' 12534'/10881 ' 6-1/8" 4-1 /2" 12.6# 13Cr Yam Ace 509' 12384'/10766 12893'/11156' Tubing 3-1/2" 9.2# 13Cr Yam Ace 12384' Surface 12384'/10766' 5 .. ) ,) NS22 Permit to Drill FORMATION MARKERS: TVDss MDrkb Pore Press. Comment formation Top estimated (Psi) (ppg EMW) Top Permafrost 1,149 1218 542 8.65 Base Permafrost 1,519 1613 708 8.65 SV6 - top confining zone 3,015 3317 1381 8.65 SV5 - base confining zone 3,287 3628 1504 8.65 Surface casing point 3,350 3699 SV4 3,597 3982 1643 8.65 SV2 - top upper injection zone 3,922 4353 1789 8.65 SV1 - top major shale barrier 4,412 4912 2010 8.65 TMBK - top lower injection zone - Top Ugnl 4,793 5347 2181 8.65 WS1 - top Schrader Bluff - Base Ugnu 6,398 7180 2903 8.65 :M3 - Base lower injection zone (top ColvillE 6,887 7739 3123 8.65 THRZ - Top HRZ 8,777 9897 3973 8.65 BHRZ - Base HRZ 8,837 9966 4000 8.65 Top Kuparuk 8,897 10037 4265 9.22 Kuparuk C 9,101 10286 4428 9.36 Unnamed fault - 50' throw 9,180 10386 Top Miluveach 9,269 10503 Intermediate casing point 9,305 10550 Intermediate logging point 9,305 10550 Top Kingak 9,791 11184 Fault 49s1 - throw = 80' 10,098 11585 Top Sag River 10,791 12489 5048 8.95 Geol target #1 10,774 12467 5015 8.95 Geologic Target #1 300' radius Intermediate casing point 10,825 12534 Top Shublik - 90 10,900 12632 5099 8.95 Top Ivishak 10,990 12749 5141 8.95 Total Depth 11 , 1 00 12893 5192 8.95 OWC estimated from Seal A-1, Oil - Water contact 11 , 1 00 12893 5176 8.95 A-2, A-3, NS #1, NS27, NS31 Total Depth 11 ,1 00 12893 5180 8.93 Top Kavik Top Lisburne 6 NS22 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ) 3699' 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 10550' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 174 - 9 5/8" x 12" 2134' 1-8 ~" 1-7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1-7" 1-7" 509' 1 - 4-112" 1 - 4-112" 12 - 4-1/2" x 5-3/4" 12- 4-1/2" x 5-3/4" 1 - 4-112" x 7" 1 - 4-1/2" x 7" 1 - 4-112" 12384' 1 1 1 1 1 1 1 1 1 2 1 ') ," 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing Head/Tbg head 95/8",47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7",26# L-80 Hydril 521 SBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger - Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-112", 12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 3-1/2",9.2# 13Cr-80 Vam Ace 3~" ABB-VGI tubing hanger 3~" ABB-VGI adapter flange 3~" ABB-VGI 5-1/8" 5K Swab Valve wI tree cap CIDRA mandrel and 0.25" fiber optic cable (w/4 ~" cable clamps). 3 ~" TRSV and 0.25" control line 3 ~" x 1 ~" GLM with dummy valve installed 3 ~" x 1 ~" GLM with RP Shear valve installed 7" x 3 ~" Baker 13 Cr packer S-3. 3 ~" WLEG (w/o holes) 3 ~" 13 Cr X nipples 3 ~" 13 Cr XN nipple 7 NS22 Permit to Drill ) ') PERMAFROST: The 13-3/8" surface casing will be run approximately 1800' TVD below the permafrost to -3699' MD I 3406' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a Permafrost 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 3026' of Open Hole + 100% excess from the permafrost to surface + 50% excess to 750'MD above the shoe. Lead TOC: Surface Tail: Based on 750' of 16" open hole x 133/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2949' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 398 bbl/539 sk 12237 fe of 10.7 ppg Permafrost 'L' Cement. 4.15 cf/sk, BHST 50° I BHCT 50° , TT = 6.0 hrs 96 bbl/466 sk 1541 fe of 15.8 ppg Premium 'G' wI 2% CaCI2. 1.16 cf/sk, BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 5720' of 12 1/4" open hole x 95/8" csg with 30% excess Lead TOC: At -3317' MD (3071' TVD) Tail: Based on 1513' of 12 'X" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -9037' MD (8080' TVD) IStage 1: Total Cement / Spacer Preflush Spacer Lead 20 bbls sea water 50 bbl Alpha Spacer wei~hted to 1.0 ppg over mud MW 415 bbll 719 sk I 2330 ft of 11.2 ppg Econolite. 3.24 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs 116 bbl/565 sk 1650 fe of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs Tail Casing 17" Drilling Liner Basis: Stage 1: Slurry: Based on 1984' of 9" open hole x 7" csg with 50% excess + 150' 9 5/8" csg x 7" csg liner lap + 20C 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -10400' MD (9247' TVD) Stage 1: Total Cement / Spacer Spacer 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Slurry 114 bbl/419 sk 1629 ft;1 of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs Casing \4-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 359' of 6 1/8" open hole x 4 ~" csg with 50% excess + 150' 7" csg x 4 ~" csg liner lap + 200' 7" csg x 4" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -12384' MD (10766' TVD) Stage 1: Total Cement / Spacer Spacer 35 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Slurry 20 bbl/76 sk 1114 fe of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs 8 NS22 Permit to Drill ) ) WELL CONTROL: ~ A Diverter waiver has been requested on well NS22. To date, BP has drilled 19 development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. Most (18) of the surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) · 5000 psi working pressure pipe rams (2) · Blind/shear rams · Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4800 psi. Surface Section: · Maximum anticipated BHP: 1504 psi @ 3287' TVDss - SV5 · Maximum surface pressure: 1110 @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 910' TVDss - Kuparuk 'C' · Maximum surface pressure: 3336 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Drilling Liner Section: · Maximum anticipated BHP: 5048 psi @ 10791' TVDss - Sag River · Maximum surface pressure: 3753 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Production Section: · Maximum anticipated BHP: 5180 psi @ 11100' TVDss - Total Depth · Maximum surface pressure: 3848 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) · Planned BOP test pressure: 4800 psi (annular to 3500 psi) · Planned completion fluid: 8.5 ppg Seawater /6.8 ppg Diesel DRilLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./ No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ./ No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. DISPOSAL: Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. 9 NS22 Permit to Drill ') ') SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. · Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS21 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. INTERMEDIATE SECTION: · Mudloggers will be rigged up throughout the entire section. · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · A small, unnamed fault will be encountered in the Kuparuk Formation. Penetration is expected at - 9180 TVDss +/- 200' TVDss. Displacement on this fault at the point of penetration should be less than 50 feet. This fault has not been penetrated by any other well. Risk of fault-related drilling problems associated with this fault is unknown. To be prepared for any potential lost circulation, a copy of the 'Non-payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. See SOR for more details. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the well bore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. · Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. · The kick tolerance for the 12 1/4" open hole section would be 105.2 bbls assuming an influx from the Kuparuk interval at -8953 TVD. This is the worst-case scenario based on a 9.84 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.3 ppg mud in the hole. 10 NS22 Permit to Drill ) ) DRilLING LINER SECTION: · Mudloggers will be rigged up throughout the entire section. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Gas in the Sag is possible. Circulate as required. According to Geology, the top of the Sag is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · Fault 49s1 will be encountered in the upper-half of the Kingak shales. Penetration is expected at - 10098 TVDss +/- 200' TVDss. Displacement on this fault at the point of penetration should be less than 80 feet. Fault 49s1 has not been penetrated by any other well. Risk of fault-related drilling problems associated with this fault is unknown. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. · The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 14.0 ppg at the 9-5/8" shoe, and 13.0 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The drilling liner shoe will be drilled out with the 9.3 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · Potential losses will be treated with the "Pay-zone" loss circulation decision tree. · The well is planned to stop short of the OWC. The Kavik will not be penetrated. The project Geologist will be in charge of picking TO above the OWC and sufficient rathole will be drilled. · The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TO. This scenario is based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. · If the Sag River top comes in low, the well will be drilled horizontally to increase the area of pay drilled. 11 NS22 Permit to Drill ) ') NS22 Ria-site Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE ....¡ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS22 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to ....450 to 500 gpm and keeping the mud temperature cool. ....¡ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. ....¡ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associat¢d methane. No indication of shallow gas was seen in any previously drilled Northstar wells. l Mudloggers will be used continuously on NS22 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. ....¡ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 ~" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. ....¡ Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ....¡ Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ....¡ The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ....¡ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ....¡ Northstar is not a designated H2S pad. ~ CONSULT THE 'NORTHST AR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 12 ') ) Permit to Drill MMS Section 250.414 (f) (5) (iv) (9) Estimated Values (ppg) 8 o 9 10 11 12 13 14 15 16 1000 -+- Pore Pressure (ppg) -ill- Mud Weight (ppg) --.- Frac Gradient (ppg) 2000 3000 - r ..-... C > 4000 I- .... CJ} ~ --- 5000 .s:: .... Q. CJ} C 6000 C) t: .- .... .... 7000 - CJ} en 0) c: .- 8000 tn CO 0 9000 -- ----. - 10000 --,--- - - 11 000 - r"'"r - 12000 I I L_._____.. õ [ KB KOP Bid 1.5/100 Crv 2/100 Crv 2.5/100 Top Perm Base Perm Report Date: Client: Field: Structure I Slot: Well: Borehole: UWIIAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: NS22 Proposed Well Profile - Geodetic Report November 11, 2002 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar d Vertical Section Origin: Northstar PF I NS22 _ty stu Y TVD Reference Datum: NS22 - b _III TVD Reference Elevation: ~;02229 Fea51 seaBed/Gr~U~~~t~:~:~~~:~:~~ NS22 (P20) S211 November 11, 2002 Total Field Strength: 45.232° 16150.00 ft /5.507/0.551 Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49132358, W 148.69331432 Magnetic Declination Model: N 6031031.560 ftUS, E 659826.690 ftUS North Reference: +1.23169393° Total Corr Mag North·) True North: 0.99992902 Local Coordinates Referenced To: Schlumberger Minimum Curvature I Lubinski 25.750° N 0.000 ft, E 0.000 f1 KB 56.1 ft relative to MSL 15.670 ft relative to MSL 26.086° 57550.115 nT 80.951° January 16, 2003 BGGM 2002 True North +26.086° Well Head ~ Grid Coordinates Geographic Coordinates MD Incl Azim I TVD VSec N/·S E/·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 6031031.56 659826.69 N 70.49132358 W 148.69331433 300.00 0.00 90.00 300.00 0.00 0.00 0.00 0.00 6031031.56 659826.69 N 70.49132358 W 148.69331433 400.00 1.50 90.00 399.99 0.57 0.00 1.31 1.50 6031031.59 659828.00 N 70.49132358 W 148.69330362 500.00 3.43 76.98 499.89 3.01 0.67 5.54 2.00 6031032.35 659832.21 N 70.49132541 W 148.69326905 600.00 5.41 73.40 599.59 8.07 2.70 12.97 2.00 6031034.54 659839.60 N 70.49133095 W 148.69320831 700.00 7.41 71.74 698.96 15.72 6.07 23.62 2.00 6031038.14 659850.17 N 70.49134016 W 148.69312126 800.00 9.40 70.78 797.88 25.98 10.77 37.45 2.00 6031043.13 659863.90 N 70.49135300 W 148.69300821 900.00 11 .40 70.15 896.23 38.81 16.82 54.46 2.00 6031049.55 659880.77 N 70.49136953 W 148.69286916 930.13 12.00 70.00 925.74 43.18 18.90 60.20 2.00 6031051.75 659886.47 N 70.49137521 W 148.69282224 1000.00 12.80 62.76 993.98 54.56 24.93 73.91 2.50 6031058.07 659900.04 N 70.49139168 W 148.69271017 ~-.; 1100.00 14.24 53.98 1091.22 74.24 37.23 93.71 2.50 6031070.79 659919.57 N 70.49142528 W 148.69254832 1200.00 15.93 46.91 1187.78 97.88 53.84 113.68 2.50 6031087.83 659939.18 N 70.49147066 W 148.69238508 1218.03 16.26 45.80 1205.10 102.56 57.29 117.29 2.50 6031091.35 659942.71 N 70.49148008 W 148.69235557 1300.00 17.81 41.24 1283.47 125.43 74.72 133.79 2.50 6031109.13 659958.83 N 70.49152770 W 148.69222069 1400.00 19.83 36.64 1378.13 156.83 99.84 154.00 2.50 6031134.68 659978.50 N 70.49159632 W 148.69205548 1500.00 21.94 32.89 1471.56 192.03 129.14 174.27 2.50 6031164.41 659998.13 N 70.49167636 W 148.69188978 1600.00 24.13 29.77 1563.58 230.96 162.58 194.56 2.50 6031198.27 660017.70 N 70.49176772 W 148.69172391 1612.64 24.40 29.41 1575.10 236.14 167.09 197.13 2.50 6031202.84 660020.17 N 70.49178004 W 148.69170290 Station ID NS22 (P20) report. xis Page 1 of 3 11/11/2002-2:44 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nl·S El·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftU S) 1700.00 26.36 27.14 1654.03 273.55 200.08 214.84 2.50 6031236.20 660037.16 N 70.49187016 W 148.69155813 1800.00 28.64 24.91 1742.73 319.71 241.58 235.07 2.50 6031278.12 660056.50 N 70.49198353 W 148.69139275 End Crv 1810.22 28.87 24.70 1751.68 324.63 246.04 237.13 2.50 6031282.62 660058.46 N 70.49199571 W 148.69137591 SV6 3316.92 28.87 24.70 3071.10 1052.04 907.03 541.09 0.00 6031949.94 660348.12 N 70.49380141 W 148.68889078 SV5 3627.53 28.87 24.70 3343.10 1201.99 1043.29 603.76 0.00 6032087.51 660407.84 N 70.49417364 W 148.68837835 13-3/8" Csg pt 3699.48 28.87 24.70 3406.10 1236.72 1074.86 618.27 0.00 6032119.38 660421.67 N 70.49425988 W 148.68825970 SV4 3981.54 28.87 24.70 3653.10 1372.90 1198.60 675.17 0.00 6032244.31 660475.89 N 70.49459790 W 148.68779443 SV2 4352.67 28.87 24.70 3978.10 1552.07 1361.41 750.05 0.00 6032408.68 660547.25 N 70.49504266 W 148.68718211 SV1 4912.23 28.87 24.70 4468.10 1822.22 1606.89 862.93 0.00 6032656.51 660654.82 N 70.49571324 W 148.68625899 TMBK 5347.31 28.87 24.70 4849.10 2032.27 1797.76 950.71 0.00 6032849.21 660738.47 N 70.49623464 W 148.68554110 ~/ WS1 7180.14 28.87 24.70 6454.10 2917.12 2601.82 1320.46 0.00 6033660.97 661090.83 N 70.49843107 W 148.68251677 CM3 7738.55 28.87 24.70 6943.10 3186.71 2846.79 1433.12 0.00 6033908.29 661198.19 N 70.49910024 W 148.68159515 Drp 2/100 9860.81 28.87 24.70 8801.56 4211.30 3777.83 1861.26 0.00 6034848.25 661606.18 N 70.50164345 W 148.67809216 Top HRZ 9896.96 29.60 24.70 8833.10 4228.95 3793.87 1868.64 2.00 6034864.44 661613.22 N 70.50168726 W 148.67803178 9900.00 29.66 24.70 8835.74 4230.46 3795.23 1869.27 2.00 6034865.81 661613.82 N 70.50169098 W 148.67802662 Base HRZ 9966.45 30.99 24.70 8893.10 4263.99 3825.71 1883.28 2.00 6034896.59 661627.17 N 70.50177423 W 148.67791198 10000.00 31.66 24.70 8921.76 4281 .43 3841.56 1890.57 2.00 6034912.59 661634.12 N 70.50181753 W 148.67785232 Top Kuparuk 10036.96 32.40 24.70 8953.10 4301.03 3859.36 1898.76 2.00 6034930.56 661641.92 N 70.50186615 W 148.67778530 10100.00 33.66 24.70 9005.95 4335.38 3890.58 1913.12 2.00 6034962.08 661655.60 N 70.50195143 W 148.67766779 10200.00 35.66 24.70 9088.20 4392.23 3942.24 1936.87 2.00 6035014.23 661678.24 N 70.50209254 W 148.67747344 KupC 10285.72 37.37 24.70 9157.10 4443.23 3988.58 1958.19 2.00 6035061.02 661698.55 N 70.50221912 W 148.67729898 10300.00 37.66 24.70 9168.42 4451.92 3996.48 1961.82 2.00 6035068.99 661702.01 N 70.50224070 W 148.67726927 Fault Crossing 10386.50 39.39 24.70 9236.10 4505.79 4045.42 1984.33 2.00 6035118.40 661723.46 N 70.50237438 W 148.67708506 10400.00 39.66 24.70 9246.51 4514.37 4053.22 1987.92 2.00 6035126.28 661726.89 N 70.50239568 W 148.67705568 End Drp 10417.19 40.00 24.70 9259.71 4525.38 4063.22 1992.52 2.00 6035136.37 661731.27 N 70.50242300 W 148.67701804 TMLV 10502.55 40.00 24.70 9325.10 4580.24 4113.07 2015.45 0.00 6035186.70 661753.12 N 70.50255916 W 148.67683039 '---' 9-5/8" Csg Pt 10549.54 40.00 24.70 9361.10 4610.44 4140.52 2028.07 0.00 6035214.41 661765.15 N 70.50263415 W 148.67672711 Kingak 11183.97 40.00 24.70 9847.10 5018.17 4511.01 2198.48 0.00 6035588.45 661927.54 N 70.50364614 W 148.67533246 Fault 49s1 Crossing 11584.73 40.00 24.70 10154.10 5275.74 4745.04 2306.12 0.00 6035824.72 662030.12 N 70.50428539 W 148.67445145 Target S21 12467.19 40.00 24.70 10830.10 5842.87 5260.38 2543.15 0.00 6036345.00 662256.00 N 70.50569301 W 148.67251122 Sag River 12489.38 40.00 24.70 10847.10 5857.13 5273.34 2549.11 0.00 6036358.09 662261.68 N 70.50572841 W 148.67246243 7" Csg Pt 12533.76 40.00 24.70 10881.10 5885.66 5299.26 2561.03 0.00 6036384.26 662273.04 N 70.50579921 W 148.67236485 Shublik 12631.67 40.00 24.70 10956.10 5948.58 5356.43 2587.33 0.00 6036441 .97 662298.10 N 70.50595536 W 148.67214955 Top Ivishak 12749.15 40.00 24.70 11 046.1 0 6024.09 5425.04 2618.89 0.00 6036511.24 662328.18 N 70.50614276 W 148.67189119 OWC 12892.74 40.00 24.70 11156.09 6116.36 5508.89 2657.45 0.00 6036595.89 662364.92 N 70.50637179 W 148.67157551 NS22 (P20) report.xls Page 2 of 3 11/11/2002-2:44 PM I TO 14-1/2" Lnr Pt Station 10 LeQal Description: MD (ft) 12892.75 Incl (0) 40.00 Azim I TVD I (0) (ft) 24.7011156.10 Surface: 1259 F8L 646 FEL 811 T13N R13E UM Target S21 : 1238 FSL 3379 FEL S1 T13N R13E UM BHL: 1487 FSL 3265 FEL S1 T13N R13E UM NS22 (P20) report.xls VSec I (ft) 6116.37 N/-S (ft) 5508.90 NorthinQ (Y) rftUS] 6031031.56 6036345.00 6036595.90 Page 3 of 3 E/-W I (ft) 2657.46 DLS (0/100ft) 0.00 EastinQ (X) rftUSl 659826.69 662256.00 662364.93 Grid Coordinates Northing I Easting (ftUS) (ftUS) 6036595.90 662364.93 N 70.50637182 W 148.67157543 Geographic Coordinates Latitude I Longitude -- -.~j 11/11/2002-2:44 PM 0.......,..;.....'.......',,".....,.,.....,..',.....b,....,.,..........,p :,:-:'::":"';1._; :'1, ",II' ) ') VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS22 (P20) Field: Northstar Structure: Northstar PF Section At: 25.75 deg Date: November 11, 2002 Schlumberger ..- ...... ~:::J \f-C/) g~ o <D N > II .8 £ CO -r-~ ,-,0 ..c~ ã.~ <D "- om -~ ~.¡..: t <D <DO::: > > <D <D :Jill ~ 0-,····· ¡ I I ~ 2000 + I i I r [ I 4000 + I I t- I 6000 04- I .1....______ I r------ 8000 I - I i I KOP Bid 1.51100 / 300 MD 300 TVD 0.00' 90,00' az ".,.. """"'TaëPârtürë"~;:;-~;~~ -.-....-.."..- ~400 MD 400 TVD 1,50' 9J.00' az 1 departJre CN 2.51100 930 MD 926 TVD - f700'-70:otJ· iiZ 43 departure ----- T T I T I T i + ! t "..,.. I I 7Js171ãõMD6454 TVõ I tM37739MD6943 rVõ I --I'· --l-- I I i ï i ....¡. .-.,..,,-..,.. I I 1 Sv6331i"MD3071TVD i Sv5 3628MD 334:3TVD 1 Sv4 3982MD 365:3TVD I '1 'Sv24353MD391åTVõ I 1 Sv1 4912MD 4468-TVD ",'.'~..",..."~''''''"....,..".._....,, .,,,,,.,n,..·_,,,,,..',"""""_ End Cry 1810 MD 1752 TVD .. ""2s':à'7;-'24.iij;'à-Ž""" 325 departure 13-3/8" Csg PI ~ 3699 MD 3406 TVD 28,87' 24.70' az 1237 departure - T - - - - - - - T - - - - - -!. I -'T I Top Përm 1218MD120Š-TV~ BãsePerm1613 MD 1575 TVID I I "[ I I I I 1 ] ! I ~ ,¡ I I I Î -i I I. I ] I I i I I 1 I i I : i TMBK5347 MD 4849 TVD ~ I ' I Hold Angle 28_'70 In i DrP 2i'100 - - 4 9861 MD 8802 TVD I _ 2a.87~24.zo' az. J _ _ _ _ _ _ 4211 departure I I 1041~MD 9260TVD - - ;~I :~':~. 9-51800 Csg PI ~ 10550 MD 9361 TVD I 40 00' 24 70· az I 4610 departure - -----+---- - - - - - - - - - - - - - - - - - _ _ _ _ J _ _ _ _ i' ! -1- ¡ 1 I I -+ I ! I ! "-r ~8g~I~~ ~ - - - - - - ~ - 1~~~~~~~M = ï l Target 521 ~ Jt'.. 1246~ MD 1~30i,.TV,. D _ -i. _ _ _ 4Q.OO .....24.Z0 ~ ,_,;. " ",5843 departure ¡ - I - - - - - - ~ I 7" Csg PI __________ 12534 MD 10881 TVD - - = .w:oo·~4:lõ· ~ = 5!!B6 dëpadiire = - .j<Jngã~J;::1~'}1º ~7TV[" Fauii49sTcrooSlng11šã5 MD {0154TVD- I I ~aQJ3'veT12~ ~TTVo- -r?~~~h~ B~¡l¥A~ --Ow::: 12&13 m5õìYrf', 10000 -- 12000 -- -2000 I o - - - - Hold Angle, 40.00° I TO 14·11200 Lnr PI 12893 MD 11156 TVD 40 00" 24 70' az 6116 departure' I 2000 I 4000 I 6000 I 8000 Vertical Section Departure at 25.75 deg from (0.0, 0.0). (1 in = 2000 feet) ö 6000 - 5000 - ~ 4000-·,· ^ I l- n:: o z 3000 - I 2000- I- :J o (f) V V V 1000 - 0- ) PLAN VIEW Client: Well: Field: Structure: Scale: Date: BP Exploration NS22 (P20) Northstar Northstar PF 1 in = 1000 ft 11-Nov-2002 Alaska Schlumberger -1000 I o I 1000 I 2000 I 3000 , True North Mag Dee ( E 26.09° 7" Csg PI 12534 MD 10881 TVD 40.00' 24,70' az 5299 N 2561 E .._~-_.._-_.__._.__.._--------_. Target 521 12467 MD 10830 TVD 40.00' 24,70' az 5260 N 2543 E ... .~...,.""..., ".-."''''...'''.."..." ..,.."~,, . ..., ".'.""""'"'''''-'.''''".,,-''''''''''" "'-'~.".'~.~~~~~~..~~'.'~~'...TVD'--.._..... 40,00' 24,70' az ~ End Dr:141 N 2028 E .. 10417 MD 9260 TVD 40.00' 24,70' az 4063 N 1993 E Drp 2/100 9861 MD 8802 TVD 2a,aiò:24,iÒ'az· .. 3778 N 1861 E k '~.. S ::::i .§ ~ ~ :f 13-318" Csg PI 3699 MD 3406 TVD 28,87' 24.70' az 1075 N 618 E Crv 2/100 400 MD 400 TYD 1.50' 9Ooo'az~ ON 1 E End Crv / \ 1810MD'1752TVO' KOP Bid 1.51100 ' " '.'" '. ;~8~· ~~7t az 300 MO 300 TVD 0.00' 90 00· az Crv 2.51100 o N 0 E 930 MD 926 TYD 1200' 70,00' az 19 N 60 E I -1 000 I o «< WEST I 1000 I 2000 EAST »> I 3000 - 6000 - 5000 .....- 4000 - 3000 . - 2000 - 1 000 -0 ) ) Schlum berger Anticollision Report C9mpany: BP Amoco Field: Northstar Reference Site: Northstar PF Reference Well: NS22 Reference Wellpath: Plan NS22 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 39.87 to 12892.75 ft Maximum Radius: 3000.00 ft Date: 11/t112002 Time: .15:05:50 Page: Co-ordinªtè(NE)'·Reference: Vertical·(TVD) Reference: Well: NS22,TrueNorth N33E 55~8 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 6/27/2002 Validated: No Planned From To Survey ft ft 39.87 1000.00 Planned: Plan #20 V1 1000.00 12892.75 Planned: Plan #20 V1 Version: 8 Toolcode Tool Name GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 3699.10 3405.77 13.375 16.000 133/8" 10549.11 9360.77 9.625 12.250 9 5/8" 12533.33 1 0880.77 7.000 8.500 7" 12892.75 11156.10 4.500 6.125 41/2" Summary < Offset Wellpath > Reference Offset Ctr-Ctr No'-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Northstar PF NS05 Plan NS05 V1 0 Plan: PI 546.57 550.00 171.42 11.39 160.04 Pass: Major Risk Northstar PF NS06 NS06 V32 498.03 500.00 162.03 8.63 153.40 Pass: Major Risk Northstar PF NS07 NS07 V33 149.64 150.00 151.39 3.12 148.27 Pass: Major Risk Northstar PF NS08 NS08 V18 349.83 350.00 140.67 6.27 134.41 Pass: Major Risk Northstar PF NS09 NS09 V14 546.96 550.00 134.57 8.72 125.87 Pass: Major Risk Northstar PF NS10 NS10 V17 596.61 600.00 111.17 9.00 102.30 Pass: Major Risk Northstar PF NS12 NS12 V23 399.35 400.00 94.92 7.55 87.37 Pass: Major Risk Northstar PF NS13 NS13 V12 498.41 500.00 93.42 8.30 85.13 Pass: Major Risk Northstar PF NS14 NS14 V11 598.49 600.00 77.38 10.23 67.14 Pass: Major Risk Northstar PF NS15 NS15 V19 449.15 450.00 71.62 7.83 63.80 Pass: Major Risk Northstar PF NS16 NS16 V34 448.63 450.00 60.51 8.98 51.54 Pass: Major Risk Northstar PF NS17 NS17 V10 500.00 500.00 52.70 7.73 44.99 Pass: Major Risk Northstar PF NS18 NS18 V11 449.49 450.00 38.48 8.83 29.65 Pass: Major Risk Northstar PF NS19 NS19 V9 550.49 550.00 30.63 9.66 20.97 Pass: Major Risk Northstar PF NS20 NS20 V1 0 500.00 500.00 20.62 7.96 12.70 Pass: Major Risk Northstar PF NS21 Plan NS21 V43 Plan: PI 599.60 600.00 11.87 10.35 1.52 Pass: Major Risk Northstar PF NS23 Plan NS23 V26 Plan: PI 399.95 400.00 10.88 7.45 3.43 Pass: Major Risk Northstar PF NS24 NS24 V14 649.54 650.00 21.00 10.82 10.20 Pass: Major Risk Northstar PF NS26 NS26 V22 600.57 600.00 38.53 9.79 28.78 Pass: Major Risk Northstar PF NS27 NS27 V29 948.46 950.00 46.45 17.09 29.53 Pass: Major Risk Northstar PF NS29 NS29 V22 349.55 350.00 69.99 6.32 63.67 Pass: Major Risk Northstar PF NS31 NS31 V14 1152.05 1150.00 83.47 20.24 63.40 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 1692.57 1650.00 209.71 33.64 176.33 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 1638.29 1600.00 224.40 32.17 192.45 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 1687.08 1650.00 214.73 29.15 185.95 Pass: Major Risk Seal Island SEAL -A-04 SEAL-A-04 V4 1809.79 1750.00 207.10 37.05 170.37 Pass: Major Risk ) ) Schlumberger Anticollision Report Company: Field: Reference Site: Reference Well: Refer~nce Wellpath: BP Amoco Northstar Northstar PF NS22. Plan NS22 Date: .11/11/2002 Time: 15:07:22 Page: Co-ordinate(NE) Reference: Vertical (fVD) Reference: Well: NS22, True North N33E 55.8 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 39.87 to 12892.75 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 6/27/2002 Validated: No Planned From To Survey ft ft 39.87 1000.00 Planned: Plan #20 V1 1000.00 12892.75 Planned: Plan #20 V1 Version: 8 Toolcode Tool Name GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 3699.10 3405.77 13.375 16.000 13 3/8" 10549.11 9360.77 9.625 12.250 95/8" 12533.33 10880.77 7.000 8.500 7" 12892.75 11156.10 4.500 6.125 4 1/2" Summary <- Offset Wellpath ----> Reference Offs~t Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Northstar PF NS05 Plan NS05 V1 0 Plan: PI 546.57 550.00 171.42 11.39 160.04 Pass: Major Risk Northstar PF NS06 NS06 V32 498.03 500.00 162.03 8.63 153.40 Pass: Major Risk Northstar PF NS07 NS07 V33 149.64 150.00 151.39 3.12 148.27 Pass: Major Risk Northstar PF NS08 NS08 V18 349.83 350.00 140.67 6.27 134.41 Pass: Major Risk Northstar PF NS09 NS09 V14 546.96 550.00 134.57 8.72 125.87 Pass: Major Risk Northstar PF NS10 NS10 V17 596.61 600.00 111.17 9.00 102.30 Pass: Major Risk Northstar PF NS12 NS12 V23 399.35 400.00 94.92 7.55 87.37 Pass: Major Risk Northstar PF NS13 NS13 V12 498.41 500.00 93.42 8.30 85.13 Pass: Major Risk Northstar PF NS14 NS14 V11 598.49 600.00 77.38 10.23 67.14 Pass: Major Risk Northstar PF NS15 NS15 V19 449.15 450.00 71.62 7.83 63.80 Pass: Major Risk Northstar PF NS16 NS16 V34 448.63 450.00 60.51 8.98 51.54 Pass: Major Risk Northstar PF NS17 NS17 V10 500.00 500.00 52.70 7.73 44.99 Pass: Major Risk Northstar PF NS18 NS18 V11 449.49 450.00 38.48 8.83 29.65 Pass: Major Risk Northstar PF NS19 NS19 V9 550.49 550.00 30.63 9.66 20.97 Pass: Major Risk Northstar PF NS20 NS20 V10 500.00 500.00 20.62 7.96 12.70 Pass: Major Risk Northstar PF NS21 Plan NS21 V43 Plan: PI 400.01 400.00 10.10 3.34 6.77 Pass: Minor 1/200 Northstar PF NS23 Plan NS23 V26 Plan: PI 349.99 350.00 10.20 3.10 7.10 Pass: Minor 1/200 Northstar PF NS24 NS24 V14 649.54 650.00 21.00 10.82 10.20 Pass: Major Risk Northstar PF NS26 NS26 V22 600.57 600.00 38.53 9.79 28.78 Pass: Major Risk Northstar PF NS27 NS27 V29 948.46 950.00 46.45 17.09 29.53 Pass: Major Risk Northstar PF NS29 NS29 V22 349.55 350.00 69.99 6.32 63.67 Pass: Major Risk Northstar PF NS31 NS31 V14 1152.05 1150.00 83.47 20.24 63.40 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 1692.57 1650.00 209.71 33.64 176.33 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 1638.29 1600.00 224.40 32.17 192.45 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 1687.08 1650.00 214.73 29.15 185.95 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1809.79 1750.00 207.10 37.05 170.37 Pass: Major Risk '-- - -----------.------- ----------------..--- .. TrauUi[]f: r~lindn .-Ulmuth (TH}+AZJ) 11kt) n Ctnttr loCtnlr-r Sc-p;Iration {6Ofl1inJ ----- --- :'.-s:-).s:s~} "'SHSI"~I!!I Northstar Northstar PF NS22 Plan NS22 Field: Site: Well: Wellpath: ~ p:: ~ ~ -3000 o UJ 0,:",.'..".....'..'.".,'.."...'..¡"b".".,',.,....,,',p ,: ',,:, !:',," "\.,.'..,,:::': ) ) Schlumberger I WELL NS22 I FIELD Northstar I STRUCTURE Northstar PF Magnetic Parameters Model: BGGM 2002 Dip: 80.9510 Mag Dec: 26.0860 Date: Januarv 16. 2003 FS: 57550.1 nT Surface Location Miscellaneous Lat: N70 29 28.765 Lon: W148 41 35.932 Slot: NS22 Plan#: NS22 (P20) S21 North: 6031031.56 ftUS East: 659826.69 ftUS Elev Ref: KB(56.10ft above MSL) Grid Conv: 1.231 r Scale Fact:0.9999 Date Drawn: 05:27:00PM 18-Nov-2002 -9000 -6000 -3000 o 6000 3000 Current ft) 9000 -6000 True North Mag Dee ( E 26.09° ) 9000 NS18 ~ 6000 6000 3000 ~ent NS151% NS12 Curre:1t N822 (P20) 821, 3000 0-- Default Color - Proposal - Survey o -3000 Current 1 -6000 N819 current' 1'"" 8eal-A-03 ',", -9000 -9000 -9000 -6000 -3000 o 3000 6000 WEST EAST Site: Northstar PF ) Drilling Target Cont:: 99'-¡" Description: Map Northing: 6036345.00 ft Map Easting : 662256.00 ft Latitude: 70030'20.495N Shape: Circle Target: S21 }ell: NS22 Based on: Planned Program Vertical Depth: 10774.00 ft below Mean Sea Level Local +N/-S: 5260.37 ft Local +E/-W: 2543.15 ft Longitude: 148°40'21.040W Radius: 300 ft .. _ . ... ,'"....,_,'_,_,_,~~___.".,._.._.,.,. _......__ ,.,__.."..w,_," _ _'___m__._ __,u._."..__.,.____ _. .on.'._ __..". ,.. "'/'5800 5100 5500 5500 54-00 N ^ 5300 5200 5100 5000 -- 4-900 4-800 ~ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ CJ ~ 0 N (Y) J l.J) LD I m 0- CJ / N N N N N N N N (Y) (Y) ~ ß I § ~ / G / / WELLHEAD: ABB-VGI 13-5/8' Multibowl 5ksi ) ) ORIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.9' NS22 Operation Shutdown 6.8PPG DIESEL FREEZE PROTECTION ~ AT +1- 200' TVD (200'MD) 9.4 ppg Seawater from 200' MD I 200' TVD to 3699' MD 13406' TVD ~ 13 3/8", 68#/ft, L-80, BTC @ 3699' MD ..4 ~ EMW = 8.95 ppg DATE REV. BY COMMENTS 11/18/02 BMH NS22 Operation Shutdown Northstar WELL: NS22 AP I NO: BP Exploration (Alaska) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8 Multibowl 5ksi ) NS22 - Proposed 133/8", 68#/ft, L-80, BTC @ 3699' MD 3 1/2", 9.2#/ft, 13-Cr, Yam-Ace TUBING ID: 2.867" CAPACITY: 0.0087 BBLlFT 9-5/8" 47# L-80 BTM-C @ 10550' MD 3.5" X NIPPLE, @ 12334' MD 3.5" X NIPPLE, @ 12354' MD 3.5" XN NIPPLE, @ 12364' MD 3.5" WLEG, @ 12374' MD 7", 26#/ft L-80, Hydril 521 @ 12534' MD PBTD @ 12813' MD TD @ 12893' MD ..4 .. M ~- B , E.- J, J DATE REV. BY COMMENTS 11/18/02 BMH ~S22 Proposed ~ \>RIGINAL KB. ELEV = 56' ^~B-BF. ELEV = 40.1' CB. ELEV = 15.9' 3 1/2" SSSV @ 1000' TVD wI HXO SVLN nipple 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (7253'MD) ~ 31/2" GLM @ 4500' TVD (4949' MD) 3 1/2" GLM @ 5866' TVD (6500'MD) ~ - 7" LINER TOP @ 10400' MD ~ ~ I 3.5" Fiber Optic Transducer -;;- _ 7" PACKER,13 Cr @ 12344' MD I I r~ ~ 4.5" LINER TOP @ 12384' MD ... ~ 4.5",12.6#, 13Cr Yam Ace Northstar WELL: NS22 API NO: BP Exploration (Alaska) 207130 DATE INVOICE / CREDIT MEMO '20/02 INV# CK091602D _1 /-"t,"'--- "-~ " ~, ! <. "'2 ( ~{'-"'" . J' "", ,_.... ~.../ " ../ ....- ,TTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY ) DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ B P r;..' 'T" ¡III Ii ¡,WI. ",,, Iri, I J ~ ¡ (" . . .. .iJ ..II.. ¡m'" 1HI" ''''"1 TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7th AVE. STE. 100 ANCHORAGE, AK 99501 GROSS ) DATE CHECK NO. 9/20/02 H207130 VENDOR DISCOUNT NET H RECEIVED NO\! 1 92002 Alaska OU & Gas Gems. Commission Anchorage . No. H 207130 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 ----;f12 ....~ fUI' 'In'lI "',n DATE SEPT. 20, 2002 1/1 2 0 7 ~ j 0 1/1 I: 0 l. ~ 2 0 jag 5 I: 00 a l. l. ~ g 1/1 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ****$100.00**** ~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 11/ S 2... 2.. Z "2, - .:2- 2., 3 PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~dJ,"¡'" &'~,7' WELL PERMIT CHECKLIST COMPANY ß tx WELL NAME A../S 2.. '2.... PROGRAM: Exp _ Dev ~ Redrll _ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL _{ 9 d N::. ~ INIT CLASS ()PÂtl' / -ð/'j GEOL AREA ?', 0 UNIT# I/. tÇ" í"':>,.,J ON/OFF SHORE ,.g£¡ , ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ry N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ~~ ~.l) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N t:t.'-- ~e>z. 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . '~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ 7 ;( ßIJ. A. (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. Y N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . &? N ~O'I @ ZOI' 16. Surface casing protects all known USDWs. . . . . . . . . . . ð2 N . 1 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ~N~ A-J.t q if Æ4,.' f .e-itZ,( ( , 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 0 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 12 N t 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 6f N ¡JC<" ~'S ~ -S E 22. If a re-drill, has a 10-403 for abandonment been approved. . . XN-, N ,~¡. 23. Adequate wellbore separation proposed.. . . . . . . . . . . . œ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-N" W Il£4 "¿'ý . 25, Drilling fluid program schematic & equip list adequate. . . . . ~.' NN ý}/La./t fJ1lJ..-I. I?:.v P (JÎ 26. BOPEs, do they meet regulation. . . . . ~'J' . . . . . . . . . ,J J2 APPR DATE 27. BOPE press rating appropriate; test to '-t..f 00 psig. . N M~ r 3 -åL/ ð pç ¡/, :.1/. A_ 1.I'l'.....JOL.. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 19, NN ""',~ rr VV{I 29. Work will occur without operation shutdown. . . . . . . . . . . 'Œ/ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y £6i2. , A- 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥'-N U"'hl JfY, '--r,j,/~j j..-v) if''Ò 1;..-- /'þJ/, Y AJ, A, N N (Service Well Only) GEOLOGY APPR DATE II/¡ P!~dh2 (Exploratory Only) 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... { GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP~ TEM JDH JBR COT DTS 11/2oþ¿ SFD I' MJW MLB 11/:2.D 1° Z. WGA Rev: 10/15/02 - G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Infornlation of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. "' f'\h'~~t~ Œ~ a (38,13 Con s, C( Hnmbt,;;)fl I\nd 1í.)f~~Li8 "'" ~"I Y r:t p "00'1 JV'I I¡ t:. ~), t. J . RE.CE\\/ED c; ~ ~~" (' \>' \-4.. :,'-. 1'"\ Î . '-....1.. END OF WELL REIJ()RT NOr~rrl~isrr AR f\!S22 Sperry-Sun HALLIBURTDN f)Od-GJCJ3 END OF WELL REPORT NORTHST AR NS22 I I I ( I ( ( ( ( ( ( I I I I I I I I BP EXPLORATION ALASKA sper'r'\(-sun [J RILL I N G 5 E R V I t:: E 5 I I I I TABLE OF CONTENTS I ( 1. General Information ( 2. Daily Summary 3. Daily Operations ( 4. Show Reports ( 5. Morning Reports 6. BHA's I 7. Bit Record ( 8. Mud Reports 9. Survey Record ( 10. Formation Tops ( 11. Formation Evaluation Logs I ( I speral""V- sun I I:IRIl..LINt:i 5eR\Ju::eS:i I I I I I ( I I ( I ( ( I ( ( ( ( I I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS22 Northstar North Slope Alaska United States 50-029-23128-00 AK-AM-22184 Nov 21,2002 Jan 22, 2003 True 26.145 deg 80.949 deg 57548 nT Nov 20, 2002 North 70 deg 29 min 28.765 see East 148 deg 41 min 35.932 see 25.750 deg Tom Mansfield Doug Wilson Mark Lindloff Reg Wilson Gavin Kidd Bob Clump Joe Polya Mike Dinger Ken Lemley Northstar 107 Alaska North Slope sperl....v-sun [J fõil L.L.I N I::ii 51: R\J I':;;; e:5 I I I I ( ( ( I I I I I I ( ( I I I I BP Exploration - N orthstar NS22 Daily Summary 11/21/02 Begin logging at 201' MD. Drilling 16" hole. NB #1 MXC-l tfa= 1.031. 11/22/02 Continue drilling 16" hole T/510" MD, POOH, RIH with BHA #2, Rerun Bit # 1 . Continue drilling F/510 T/1557' MD Max Gas was 18 Units at 1260' MD, Avg ROP 190 ft/hr. Top of Permafrost 1195', MD 1190' TVD Bottom of Penna frost 1625' MD. 1564' TVD 11/23/02 Continue to drill F/1557, T/3725. Circulated hole clean Start POOH. Max Gas 35 Units at 2824' MD, Avg ROP 236 ft/hr. Top ofSV6 3347" MD, 3091" TVD Top of SV5, 3666' MD, 3368" TVD 11/24/02 Run 13 318" casing to 3706' MD. Cement same. 11/25/02 Displace well with Brine and Diesel. Nipple down riser. Decision to stay on NS22 well and drill 12 1¡4" hole. Due to lack of ice thickness. Nipple up Bop's. Will sling load 9 5/8" casing out by helicopter. 11/26/02 Continue to nipple up BOP's. Test BOP's 11/27/02 Run in hole with BHA #3 ( 12 1¡4" MX-CIDT , TFA= 1.006) with a 1.150 mud motor to 3615' MD. Test casing to 3500 psi for 30 minutes-OK. Drill float. Displace 9.4 ppg brine with new mud. Due to weather cannot fly out casing. Wait on weather. 11/28/02 Weather conditions kept helicopters grounded until 0700 hours. Resume sling loading 9 5/8" casing and wait to drill to ensure that helicopter operations proceed smoothly. Drill out shoe track and 20' of new formation to 3745' MD. Circulate until MW in = MW out, 8.5 ppg. Perfonn Leak Off Test to 11.9 ppg EMW 3 times. Drill ahead to 4118' md. Top ofSV4 marker at 4006' MD, 3672' TVD. Maximum gas 32 units at 3996' MD. 11/29/02 Drill 12 1¡4" hole from 4116' to 6654' MD. Top ofSV 2 marker at 4472' MD, 4080' TVD. Top of the SVl marker at 4941' MD, 4483' TVD, Top of the UGNU fonnation at 5347' MD, 4839' TVD. Maximum gas 591 units at 6160' MD. 11/30/02 Drill 12 1¡4" hole from 6654' to 7738' MD. CBU. Circulate high fibre sweep. Trip out of the hole to the 13 3/8" casing shoe. Top of the Schrader Bluff formation at 7148' MD, 6432' TVD. Bit #2 statistics= 4013 feet, 29.7 hours and 165K revolutions. 12/01/02 Continue to POOH to 13 318" casing shoe. Wait on helicopters to sling load casing to island. Continue to POOH. Test BOPs. Make up new bit and BHA. RIH to 13 3/8" casing shoe. Work on pump manifold. 12/02/02 Continue to RIH. Trip gas of 102 units. Drill ahead from 7738' to 9145'. Packed off at 8527' with PWD of 13 ppg. Lost fluid returned with pumps off. Packed off zone returned 295 units from bottoms up. Top of Colville at 7799' MD, 7004' TVD. I I I I I I I I I I I ( ( ( ( I I I BP Exploration - N orthstar NS22 Daily Summary 12/03/02 Drilled from 9145' to 10246'. Added spike fluid to bring mud weight from 9.2 ppg to 10.1 ppg. Maximum gas was 467 units from the HRZ at 9851'. Top ofHRZ at 9839' MD, 8795' TVD. Base ofHRZ at 9930' MD, 8871' TVD. Top of Kuparuk at 10040' MD, 8961' TVD. 12/04/02 Drilled from 10246' to 10743', total depth for 9 5/8" casing. Circulated hole clean. POOH to run 9 5/8" casing. Began pulling tight at about 7930'. Pump out to about 6500'. Continue to POOH. 12/05/02 Finish POOH. Repair top drive. Change out rams. Start running 9 518" casing at 17:30 hrs 12/06/02 Run 95/8" casing and land casing at 10680' MD. Rig up to cement casing. Establish circulation, Max Gas 1816 units. Clear annulus with 230bbls of mud at 'li bbl/min. 12/07/02 Finish clearing Annulus. Test BOPs. Change kelly hose. New kelly hose too short. Prepare to re- install original hose. 12/08/02 Finish re-installing kelly hose and pressure test. Pick up new BHA and run in hole to float collar. Pressure test casing. Ream down to 10743' MD. 12/09/02 Drill to 10992' MD. Pull out of hole to check bit. Repair pump. Change out MWD and damaged BHA. 12/10/02 Run in hole to shoe. Wash to bottom slowly. Drill ahead from 10992' MD to 11185' MD. Top of Kingak Fonnation at 11155' MD, 9849' TVD. 12/11/02 Drill ahead from 11185' MD to 12469' MD. Top of Sag River fonnation at 12449' MD, 10818' TVD 12/12/02 Drill ahead from 12469' MD to 12487' MD. TD 8 'li" hole section at 12487' MD, 10845' TVD. Wiper trip to shoe. Trip out of hole 1/17/03 Move rig back to NS22. Nipple up BOP's and preform BOP test. Circulate out diesel with sea water. 1/18/03 Pressure test Casing to 4700 psi. Pick up BRA and run in the hole with same. Drill out plugs and landing collar. 1/19/03 Perfonn FIT to 11.5. Drill ahead to TD 12866' MD, 11149' TVD. ROP F/35 T80ft/hr. Max gas was 680 units. Top of Shublik 12632 MD, 10953' TVD, Ivishak 12730' MD, 11028' TVD. CBU, POOH. Drill ahead 16" surface from 1561' md to 1655' md. Gyro. Drill ahead fl 1655' to 1749' md. P ISM. RD Schlumberger and Gyrodata. Drill ahead fl 1749' to 3725' md into SV-5 (Casing point + 19' rat hole). - Final projected inclination at TD is 29.42 degs. Azimuth 22.54 degs. - Overall average ROP 225 fph. - Pump hi-vis sweep every 400'. - Total Flow was increase to 1050 gpm. Screen blinding forced dropping flow rate for the last 375'. - TD parameters: 40 rpm wi 13 K-Ibs torque; 730 gpm wI 1480 psig on; WOB 35K lbs. Pump 70 bbls hi vis weighted LCM sweep and circulate surface to surface. - Circulate IX BU @ 750 gpm - Increase rate and circulate @ 1025 gpm for 1.5 x BU. Returns clean. Monitor well. Pull 5 stds off btm (PU WT= 200K, RIH WT= 150 K lbs). - Hole in good condition, pump dry job. Blow down TD. Continue POOH to HWDP. - Check Trip good. Max drag 20 K @ 2452'. Swabbing at DL's @ 1209' and 1020' md. Usual buildup of clay on tool joints on the way out Drill ahead 16" surface hole from 274' md to 510' md wI BHA #1. - AST= 1.1 hrs. - ART= 0.1 hrs - Gyro time= 2.6 hrs. In better shape directionally. Outside hardline for 500'-1000' md. CBU. POOH for BHA#2 (MWD). Drill ahead 16" surface hole from 510' md to 546' md wi BHA #2. CBU. Gyro. Find and fix leak in possum belly. Drill and slide from 546' to 816' md. Run Gyro. Drill and slide ahead 16" surface hole from 816' to 1277' md. Run Gyro. Service Top Drive and drawworks. Drill and slide 16" hole from 1277' to 1561' md. Run Gyro. Operations Breakdown 21:30-22:00 3,725 0.50 22:00-00:00 998 2.00 19:00-21 :30 3,725 2.50 07:00-07:30 510 0.50 07:30-10:30 510 3.00 10:30-11 :00 546 0.50 11 :00-12:00 546 1.00 12:00-13:00 546 1.00 13:00-15:00 816 2.00 15:00-15:30 816 0.50 15:30-19:00 1,277 3.50 19:00-20:00 1,277 1.00 20:00-20:30 1,277 0.50 20:30-23:30 1,561 3.00 23 :30-00:00 1,561 0.50 11/23/02 00:00-00:30 1,655 0.50 00:30-02:00 1,655 1.50 02:00-02:30 1,749 0.50 02:30-03 :30 1,749 1.00 03:30-19:00 3,725 15.50 Time Elapsed (hrs) Time 11/22/02 00:00-07:00 510 7.00 BP Exploration - Northstar NS22 Daily Operations (I.A.D.C) I ( ( I I I ( ,I I I I I I I I I I I I I J I ( ( 1 I 1 I 'I I 11/24/02 00:00-04:00 4.00 04:00-05 :30 05 :30-06:30 06:30-08:00 08:00-08:30 08:30-17:00 1.50 1.00 1.50 0.50 3,650 8.50 17:00-17:30 3,707 0.50 17:30-20:00 3,707 2.50 PJSM for Cement Job. 20:00-20:30 3,707 0.50 20:30-22:30 3,707 2.00 22:30-23:30 3,707 1.00 I I 23 :30-00:00 3,707 0.50 I 11/25/02 I 00:00-02:30 2.50 02:30-04:00 1,375 1.50 I 04:00-06:30 2.50 I 06:30-11 :00 4.50 Continue out of hole w/ BHA#2. -Stand back Drill Collars - LD BHA and make service break on stabilzer blades. - Bit graded 2-3-WT-A-E-I-NO-TD Clear and clean rig floor. Remove bails and elevators. Repair pipe shed hoist. PJSM. Rig up the floor to nm 13-3/8" casing. PJSM on running 13-3/8" casing. MU float equipment to 12000 ft-lbs torque, Bakerlock connections. - Circulate shoe-track volume. PU and RIH, Floats good. - Had to washJwork past 2506 ft. - Run 15 joints of 13-3/8" 68# L-80 wi cent floating, including shoe-track. - Continue Running 89 jts total 13-3/8" 68# L-80 BTC casing. MU torque average 8000 ft-Ibs. MU fluted hanger wi pup jt, landing joint, and land casing. - Install cement head. -Slack of weight when landing was 175 klbs( including blocks) Establish circulation and work rate up to 11.2 bpm @ 425 psig. - Getting cleanup at higher rate. Switch to 75 bbls of Sea Water- Bicarbonate pill. P Pump 5 bbls sea water. Pressure test to 3000 psig. Pump cement job as per plan: 1) Mix and pump 75 bbls of 10.5 ppg Alpha Spacer @ 6 bpm. 2) Drop bottom plug. 3) Start mix and pump 453 bbls (615 sxs) of 10.7 ppg lead cement @ 7 bpm. 4) Start mix and pump 97 bbls (470 sxs) of 15.9 ppg tail cement @ 5 bpm. 5) Drop Top Plug. Flush out top plug wi 25 bbls Sea Water ITom HALCO. - Switch to rig pump wi lOA ppg NaCL brine for displacement. - Catch plug @ 800 strokes. - Displace @ 10 bpm. At 3400 strokes drop rate to 8 bpm. Good cement back to surface. Up rate to 9.0 bpm after turning on sea water and jetting wi Citric solution from trip tame - Slow rate to 5 bpm @ 4950 strokes wi 950 psig prior to bump. - Bump plug at 5131 strokes (96.1% pump effcalc) 541 bbls total displacement on HALCO meter. -Hold 1500 psi for 7 nlins. Bleed off and check floats. - Prepare to rig down cement head. Remove casing elevators. Back out top section of landing jt. Pull master bushings. Drain and flush riser & flowline. P JSNf. Change out bales and elevators. Rill wi DC's, TI\V valve, HWDP, and DP to 1375' to displace brine [rool wellbore. PJSM. POH and LD 15 jts DP, 26 jts ofH\VDP, Jars, and 3- DC's. P JSM. LD iYfousehole, ND riser & riser adapter. I 11 :00-12:00 l.00 I 12:00-14:00 2.00 ì 4:00-15 :00 1.00 I 15 : 00-18 : 00 3.00 I 18:00-19:30 1.50 19:30-00:00 4.50 I 1 11/26/02 00:00-02:00 2.00 02:00-05:30 3.50 I 05:30-06:30 1.00 06:30-09:00 2.50 09:00-13:00 4.00 13 :00-20:30 7.50 20:30-00:00 3.50 1 11/27/02 00:00-01 :30 1.50 01 :30-02:00 0.50 ( 02:00-03:00 1.00 ( 03:00-08:00 5.00 08:00-09:30 1,000 1.50 1 09:30-11 :30 3,615 2.00 11 :30-13:00 3,615 1.50 13:00-13:30 3,615 0.50 I 13:30-14:30 3,615 1.00 14:30-16:00 3,615 1.50 16:00-00:00 3,615 8.00 I I I I I 11/28/02 ! 00:00-18:30 3,615 18.50 NU and test lVlultibowl WH to 2000 psig. RU and fill well wi diesel- 30 bbls. Land and test hanger to 5000 psig. Fill hanger void with oil. Install cover onWH. Clean pits, reinstall cellar heater, clean up drip pan, service top drive. service draw\vorks, grease crown, and install cover on trip tanle ****Ice thickness to south-dictates plan change (Consult with Anchorage Engineering) . Only 14" - need 18". Change oil in top drive. Pull tubing hanger. NU BOP stack. Mix mud for 12.1/4" intermediate hole, unload pipeshed of 4.1/2" tubing, bring 12.1/4" tools into pipeshed, and prepare for intermediate hole section. N/U BOP's. PJSM - Repair hinge seals on shear ram door. PJSM - Install test plug, test joint, & RID to test BOP's. Clean rig while mixing mud. Test BOP's to 4800/ 250 psi for 5 I 5 min. PJSM - change out upper IBOP. Test BOP's to 4800 I 250 psi for 5 I 5 min. BID choke line. Pull test plug, install wear ring, & BID lines. PJSM - Rill wi 4 stds. DP PJSM - Displace 30 bbls. diesel back to trip tank and onto G & I through mud header line, by-passing G & I injection tanks and pumped directly downhole into NS-I0 via G & I injection pump. PJSM - PIU BHA, orient MWD, change bend on motor, & change out 3 stab. sleeves. P/u 26 jts. HWDP & RIH. Rill to 3560' & wash down to 3615'. Circulate for casing test. Test 13 3/8" casing to 3500 psi & hold for 30 minutes. Drill out float collar. Circulate new mud displacing out 9.4 brine. No helicopters due to weather restrictions. Waiting on 9 5/8" casing to be slung to location. Have only flown 10 jts. so far and want to ensure this operation runs smoothly before drilling ahead. Notes: 1) Safety stand down to discuss remedies for future safety at Northstar. 2) Service top drive. 3) Grease all sheaves in derrick, crown, & drawworks. 4) Rehung derrick climber. 5) Clean & grease air slips. 6) Organize BOP parts room. 7) Remove links from drag chain. 8) Clean motorrnans room & general clean up of rig. 9) Circulating 5 min. every hour @ 50 SPiV!. Moving pipe every 3 hrs. Weather conditions kept helicopters grounded until 07:00. Nfoved 'I I I I I 18 :30-19:30 3,745 1.00 ( 19:30-20:30 3,745 1.00 20:30-21 :00 3,745 0.50 1 21 :00-00:00 4,121 3.00 I 1 11/29/02 00:00-21 :00 6,468 21.00 I 1 1 21 :00-21 :30 6,468 0.50 21 :30-00:00 6,656 2.50 ( 11/30/02 00:00-19:00 7,739 19.00 I I I 19:00-20:00 7,739 1.00 20:00-20:30 7,307 0.50 I 20:30-21 :00 0.50 21:00-23:00 3,645 2.00 I 23 :00-23 :30 3,645 0.50 I 23 :30-00:00 3,645 0.50 personnel & then started slinging 9 5/8" to location. RetÌ"ained from drilling ahead until pipe slinging was well under way to ensure smooth operation. Notes: While waiting on weather 1) Perform maintenance on iron roughneck. 2) Plumb in new caustic hopper. 3) Chinking rig ( Sealing gaps for weather) 4) Safety stand down from 03:00 - 05:00. 5) Repair top drive oil light. 6) Troubleshoot link tilt air regulator. 7) Grease & repair agitators in pits. 8) General cleaning, scrubbing & organizing on rig. Drill out remaining cement in shoe track, rat hole & 20' of new 12 1/4" hole to 3745' md. CBU until MW in = MW out. 8.5 ppg Perform LOT to 11.9 EMW wi 8.5 ppg MW @ 600 psi. Pressure leaked off at 600 psi- repeated 3 times. Projected KIck Tolerance at TD is 64 bbls at a Pore pressure 0.5 ppg over Kuparuk Pore Pressure. Drill from 3745' to 4121' md in 12 1/4" hole wi 95/8" XP motor wi 1.15 deg. bent housing. ART 1.56 hrs. AST 0 hrs. Drill 12 1/4" hole from 4121' to 6468' md. wi 95/8" motor wi 1.15 deg bent housing. Notes: 1) Pumping hi-vis sweeps every 500' wi no visible increase of cuttings @ shakers. 2) Backreaming/ wiping a little rough on the first 40 ft of each standmight be due to the porcupine reamer. Service top drive. Continue drilling ahead from 6468' to 6656' in U gnu. Last survey @ 6577' Incl. 27.96, Az. 24.31. Drill ahead in 12 1/4" hole wi 95/8" motor wi 1.15 deg bent housing from 6656' to 7739' md pumping hi-vis sweeps every 500'. Notes: Survey @ 7661' incl. 28.20, Az. 24.67 Added 2 % lubricants before POH for next bit nIn. Stopped drilling in a sandstone to pre-empt any bit balling when drilling resumes. Pump hi-vis walnut I barofibre sweep & circulate 1 1/2 BU. Hole clean. Monitor well & POH wi 5 stds. Pump dry job & BID lines. POR to shoe & monitor well. 2 stands at the top of the Schrader & at the U gnu / Schrader interface had 50,000 & 55,000 Ibs. drag that required wiping once & they cleaned up well. The rest of TOH was slick. P JSM - Cutting drilling line. Cut drilling line. Trip tank on the hole to monitor for any potential losses. I I 12/01/02 OO:ûû-Oi :00 1.00 P JSM - cut & slip drilling line. 01:00-03:00 2.00 P JSM - Service top drive, drawvvorks, blocks, tighten & replace brake I block nuts, adjust brakes & kick rollers. 03 :00-05 :30 2.50 Wait for helicopter operations to resume for slinging 9 5/8" casing. \\- ait at shoe for possibility of RIH if slinging ops. are delayed. I PJSM - RelTIOVe mud discharge manifold on mud pump # 2. 05 :30-06:00 0.50 Break circulation, pump dry job, BID top drive & lines. Lost 15 bbls. while circulating across the top of hole. I 06:00-08:00 2.00 PJSM - POH, LID porcupine reamer, std back RWDP. Monitor well. 08 :00-1 0:30 2.50 PJSM - LID BRA - clean & clear floor. Bit graded 3/4 I 10:30-11 :30 1.00 PJSM - Pull wear ring & install test plug. 11 :30-13:00 1.50 RIU to test BOP's. 13 :00-17:30 4.50 Test BOP's to 4800 I 250 psi for 5 I 5 min. Test annular preventer to 1 3500 psi. 17:30-18:00 0.50 Pull test plug & install wear ring. 18:00-18:30 0.50 BID lines & line up choke manifold. I 18:30-19:00 0.50 PJSM - M/U BRA. 19:00-21 :00 2.00 M/U BRA # 4. 21 :00-21 :30 0.50 Shallow test MWD & BID lines. I 21 :30-23 :00 1.50 PJSM - CIO swivel packing. 23 :00-00:00 1.00 PJSM - Service top drive, blocks, & crown. * Work on-going throughout the day removing & replacing discharge I manifold on mud pump # 2 since 03:00. 12/02/02 I 00:00-01 :30 1.50 Complete installation of new mud pump discharge manifold. Continue servicing top drive & replace swivel packing. 01 :30-03:30 2.00 Rlli P Tlli to shoe. 1 03 :30-04:30 1.00 Fill pipe, break circulation & test mud pump wi new manifold, swivel packing, & rebuilt TIW valve. OK 04:30-06:00 1.50 Tlli to 6819' & wash through tight spot @ 3.5 BPM. Rlli to 7400'. 06:00-07:00 1.00 Wash & ream to 7739' from 7400'. 07:00-07:45 0.75 Circulate 1 BU staging up to drilling rate. I 07 :45-11 :30 3.75 Drill from 7738' to 8163' in 12 1/4" hole wi 9 5/8" motor wi 1.15 deg. bent housing. No Drag, No Losses. Backreaming on connections smooth. I 11 :30-12:00 0.50 Clean suction screen & replace valve spring in # 1 mud pump. 12:00-00:00 12.00 Drill from 8163' to 9135' in 12 1/4" hole wi 9 5/8" motor wi 1.15 deg. bent housing. I Notes: 1) Packed off @ 8527' & lost partial returns momentarilly. 17.0 ppg ECD spike. Was able to work pipe, regain full returns & continue drilling ahead. I Resistivity log showed invasion at the point of the stabiliser. 2) ECD's in 9.7- 9.8 range. 3) Pumping hi-vis sweeps every 400'. I 4) Survey @ 9012' n1d. lncl. 28.76, Az. 24.74 12/03/02 I 00:00-09:30 9.50 Drill & slide in 12 1/4" hole from 9135' to 9757'md wi 9 5/8" motor \v/ BID top drive & mud lines from pumping dry job, POH to shoe, monitor well, continue POH & standing back HWDP, & monitor well. OK Remaining TOH was good wi no drag or losses. PJSM - flush BHA & BID, LID BHA. Clean & clear floor - remove bails. PJSM - Pull wear ring & install test plug. P JSM - CIO upper rams to 9 5/8". PIU casing equip't & bring to rig floor. Replace break-out ram on top drive. Continue repairs on top drive break-out ran1. Test door seals on BOP's to 3500 psi. PJSM - Install mousehole & pull test plug. Install mousehole & pull test plug. P JSJ\tl - RiD Frank's fill up tool. P JSJ\tf - Install long bails. I ) I r 09:30-11 :30 2.00 11 :30-21 :00 9.50 I I 21 :00-21 :30 0.50 21 :30-00:00 2.50 r ( 12/04/02 00:00-12:00 12.00 I 12:00-14:30 2.50 1 14:30-15:00 0.50 ( 15:00-15:30 0.50 15:30-21 :00 5.50 I 1 21 :00-00:00 3.00 I 12/05/02 I 00:00-04:30 4.50 I 04:30-08:00 3.50 08:00-08:30 0.50 I 08:30-09:00 0.50 09:00-10:00 1.00 10:00-12:00 2.00 I 12:00-14:00 2.00 14:00-14:30 0.50 I 14:30-15:00 0.50 15 :00-15 :45 0.75 15:45-16:00 0.25 I 16:00-16:30 0.50 Drill & slide in 12 1/4" hole from 10231' to TD @ 10743' wi 95/8" motor wi 1.15 deg bent housing. Top ofMiluveach @ 10670' md - 9467' TVD. Pump hi-his sweep prior to TD. Pump 50 bbl hi-vis weighted sweep & circulate 1.25 B/U. Hole cleaned up. Condition mud for casing. Stood back 3 stands while circulating. Troubleshoot & identify hydraulic cylinder seal out on top drive pipe handler. Rill from 10320' to 10735' & tag fill. (8') Monitor well- POH to 7956'. Tight spots wi 40,000 - 100,000 lbs. drag in Kuparuk & HRZ from 10300' to 9656'. No swabbing. Dry wipe tight spots. P/U weights did not decrease significantly on wiping, but running back in was never a problem wi S/O weights 195 - 210K. Consensus is we can get casing down. Trip rrom 9656' - 7956' was good wi avg drag 15K Pump out of hole due to tight hole & swab from 7956' - 68311 (Schrader) POH from 6831' to 6645' wi 15K drag & no swab. Pump dry job. 1.15 deg bent housing. Notes: 1) Pumping hi-vis sweeps every 400' 2) 2 % lubricants in mud system. (Torque trim & EP mudlube) PJSM - Bleed in 12.7 ppg spike fluid off bottom as not to interfere vv. recent slide. MW 10.1 ppg after bleed in. Drill & slide in 12 1/4" hole fron1 9757' to 10039 'md wi 9 5/8" 111otor wi 1.15 deg bent housing. 1) Sliding 40' - 60' on most stands. 2) Survey @ 9951' Incl 34.35, Az 25.79 Service top drive. Drill ahead from 10039' to 10231' md. Top ofHRZ 9839' md - 8795' TVD Top ofKuparuk 10066' md - 8982 TVD Max. gas @ 467 units I 16:30-17:30 1.00 P JS1\;1 - RiU spiders, elevators, & casing tongs. I 17:30-22:30 5.00 M/U shoe track, engage Frank's tool & check floats. Rill wi 9-5/8" 4. 71b. L-80 Mod. Butt. to 13-3/8 casing shoe. 22:30-23:00 0.50 Circulate casing volume at shoe @ 9 BPM 560 psi. I No losses. 23 :00-00:00 1.00 Continue RIH w/ 9 5/8" casing. ( 12/06/02 00:00-08:30 8.50 Run 9 5/8" casing from 4400' to 10635 n no problems. - Ran a total of 260 jts. 9 5/8" 471b. L-80 Mod. BTC. ( - Hole took 50 bbls while running casing. 08:30-09:00 0.50 M/U casing hangar, landing jt, & land casing wi 190K wt. in slips. Not necessary to wash down. ( 09:00-09:30 0.50 LID Frank's fill up tool & M/U x -over & cement head. 09:30-13 :30 4.00 Establish circulation @ 1/2 BPM & stage up pumps in 1/2 BPM increments to 3 BPM; 1 BPM increments thereafter to 10 BPM. ( - ICP @ 1/2 BPM 1050 psi - FCP @ 10 BPM 730 psi Notes: I 1) Circulated additional hour due to electricians changing out on Island. Electrician needs to be available for backfeeding G & I and Halliburton wi rig power in the event of power shutdown with Island solars. 1 2) Held cement job PJSM while circulating. 13:30-14:00 0.50 Pump 5 bls. water & pressure test cement lines to 4000 psi. 14:00-17:00 3.00 Pump 50 bbls 11.0 ppg spacer & drop bottom plug. 1 Pump 415 bbls (720 sx) type "G" lead cement followed by 116 bbls (565) sx type "G" tail & drop top plug. Wash up on top of plugs wi 25 bbls water from HOWCO. 1 Switch over to rig pump & displace cement wi 751 bbls. 10.1 ppg mud. (Last 30 bbls switched over to sea water) Bumped plug wi 1700 psi @ 94.5% PE. Took pressure to 2200 psi & held for 2 min. Pressure held. 1 Howco meter read 744 bbls. NO Losses noted during cement job. 17:00-18:00 1.00 Check floats - OK. LID cement head & landing Jt. I 18:00-18:30 0.50 Set packoff & test to 5000 psi for 10 min. 18:30-19:00 0.50 Hook up kill line to 13 3/8" x 9 5/8" annulus. 19:00-21 :00 2.00 Clean & clear rig floor of casing tools. CIO bails. I Begin pumping down 13 3/8" x 9 5/8" annulus wi 10.1 ppg mud. Pumped 230 bbls @ 1/2 BPM. Pressure broke over @ 1400 psi, final pressure I 910. Cleaning L pits. 21 :00-00:00 3.00 PJSM, HACL on removing kelly hose. Disconnect hose from top drive & I standpipe. 12/07/02 I 00:00-00:30 0.50 P JSM on LID kelly hose. Con1plete flushing 13 3/8" x 9 5/8" annulus \'1/ 230 bbls 10.1 ppg n1ud @" 1/2 BPM. I Broke over @, 1400 psi - final pressure 910 psi 00:30-02:30 2.00 LID kelly hose, string out ne\v one on pad & P/u new hose. 02 :30-03 :00 0.50 Lay new hose back down & tie back 7 stands HWDP back in fingers. I 03 :00-04:00 1.00 Remove 9 5/8" top rams & replace \'1/ 7" x 4 1/2" variables. Remove kelly hose from standpipe & lower to ground. PJSM - PfU original kelly hose & MIU to standpipe. PJSM - MIU x-over & kelly hose to "S" pipe on top drive. PJSM - Test kelly hose to 4000 psi - BID lines. PJSM for MIU BHA. M/U BHA # 5. Shallow test power drive & MWD @ 550 GPM 825 psi. - Control collar failure on power drive -- change out. Retest power drive - OK Replace flow valve on pipe handler & re-sequence. Continue MIU BHA. Rill wi HWDP. Rill to 10498' md. Tagged cement 70' above float collar. Wash down from 10498' to 10589'. Condition mud & circulate. PJSM - Adjust kelly hose, re-orient rotary hose x-over @ S pipe :1 04:00-04:30 0.50 I 04:30-09:30 5.00 09:30-11 :30 2.00 I 11:30-12:00 0.50 I 12:00-13 :00 1.00 13 :00-14:30 1.50 I 14:30-15:00 0.50 15:00-16:30 1.50 ( 16:30-18:00 1.50 18 :00-20:00 2.00 r I 20:00-22:30 2.50 1 22:30-00:00 1.50 I I 12/08/02 00 :00-06 :00 6.00 r 06: 00-07 :00 1.00 07:00-07:30 0.50 ( 07:30-08:00 0.50 08 :00-09:00 1.00 I 09:00-09:30 0.50 09:30-10:30 1.00 I 10:30-11 :00 0.50 11 :00-12:00 1.00 12:00-15:30 3.50 I 15:30-16:00 0.50 16:00-16:30 0.50 16:30-18:00 1.50 I connection. 18:00-19:00 1.00 I 19:00-19:15 0.25 I 19: 15-23:00 3.75 PJSNI - pressure test 9 5/8" casing to 4100 psi for 30 min. - Review D2 & D5 drills. - PJSM for spike fluid addition. - Casing test satisfied retest on rotary hose. BID kill line. Drill float collar & plugs and cleaned out rathole to 10743' md. - Added RlU BOP testing equip't. Test BOP's to 250/ 4800 psi & hold 5 / 5. Test annular preventer to 3500 psi. Hang new kelly hose to stand pipe & atten1pt to connect at top drive. Will not fit - not enough tolerance for M/U on top drive. \Vill need to modify. C/O kelly hose softeners. Remove x-over between "S" pipe on top drive & kelly hose for modification. (extension) Hammer up kelly hose on standpipe. Bring 8 1/2" BHA tools to rig floor. Pull test plug & install wear ring. M/U BHA up to CDR & Rill. Welder complete w/ x-~ver extension modification. MID x-over extension to "S" pipe & install kelly hose to x-over. Kelly hose too short; ~6' shorter than previous hose & doesn't allow top drive to reach stops at bottom rails. Remove kelly hose. There is a new hose the proper length @ Nabors yard, but helicopters are unable to fly with current ceilings of 200'. Will mobilize new hose @ earliest opportunity. Remove "S" pipe from top drive & tie kelly hose directly into goose neck. Plenty of clearance up & down, but bow in hose will not allow tripping pipe due to interference with latching elevators. Remove kelly hose & reinstall "S" pipe on top drive. Current plans are to hook up hose that was removed originally & C/O during rig move. I I 23:00-00:00 1.00 r 12/09/02 ( 00:00-01:15 1.25 01: 15-02:45 1.50 ( 02:45-03 :45 1.00 03:45-04:30 0.75 ( I 04:30-14:00 9.50 1 14:00-14:30 0.50 1 14:30-15:00 0.50 15:00-18:30 3.50 ( 18:30-20:00 1.50 spike fluid while drilling shoe track while increasing 12.7 ppg MW. - Experienced packing off while drilling rathole \vl 2 ECD spikes to 14.8 ppg EMW. Pulled into shoe and work pipe while cleaning up hole. - 505 GP!v1120 RPM. 20:00-00:00 4.00 I 12/10/02 00:00-02:30 2.50 ( 02:30-03:00 0.50 03:00-04:00 1.00 I 04:00-04:30 0.50 04: 3 0-09: 00 4.50 I I I 09:00-10:00 1.00 10:00-11 :00 1.00 11:00-13:30 2.50 I 13 :30-19:00 5.50 I Ream back through rat hole to 10743' @. 510 GPM, 80-100 RPrvL Rat hole sticky & packing off. Drill 20' of new hole from 10743' - 10763'. Pull back to shoe & perform FIT to 14.5 EMW wi 12.7 ppg MW wi 900 pSI. Ream to 10763' & take ECD baselines as follows: o RPM - 13.68 60 RPM - 13.78 120 RPM - 13.84 Drill from 10763' to 10992' ROP's 15' - 40' FPH Discharge manifold on # 2 mud pump leaking @ flange where the newly replaced manifold makes up to the old. Decision made to POH for bit & pump repaIrs. Monitor well & pull 4 stands to shoe. Monitor well- pump dry job - BID lines. POH to HWDP Repair pump manifold while POH. Handle BHA. CDR & flex lead collar were worn flat on side & bent. Required changing out. Suspected damage occurred while drilling rat hole. Bit had one nozzle plugged but looked good. 0 - 0 with 1 chipped tooth. Handle BRA # 6. Replace control collar electronics & PIU new bias unit. - Shallow test - OK Continue Rill wi BRA # 6. LID Hydraulic jars & swap out wi new set due to leaking seal. RllIw/HWDPt0991' RllI to 10584' filling @ stds. 20, 65, 102. Note: Seemingly lost returns while Rill with stands 16 thru 20. * filled backside w/13 bbls and filled drill pipe w/15 bbls. * calc pipe fill was 32 bbls versus 28 bbls to fill hole and pipe. * determined float stuck open between stands 15 and 20. * circ drill string volume at 4 bpm to clear string of debris. * inc pump rate to 600 gpm and verify pressure to ensure jets not plug and MWD pulse -- everything is fine. PJSM - Review procedures & obtain all work permits. Cut drilling line & adjust brakes. Service top drive & drawworks. Grease crown, check bolts on # 2 mud pump manifold, check unions on kelly hose & "S" pipe. Rill to 10744' and tagged up. Est circ & rean1 to 10992' md. Notes: - 10743' md is the TD of 12-1/4" rathole. 'I I' - Reamed 8-1/2" hole vd80 rpm, 500 gpn1 and 6K avg WOB. I - Rotary stalls out & hole attempts to pack off if too aggressive. 19:00-00:00 5.00 Drill ahead in 8 1/2" hole wi RSS from 10992' to 11170' n1d. Notes: I - Experienced some bit balling - treated wi 2 nut plug sweeps. - Rap 50' - 60' in Miluveach. I 12/11/02 00:00-20:00 20.00 Drill w/RSS f/ 11860' -- 12297' md. Notes: 1 - RSS responding well to downlinks. - PWD measuring ECD @ 0.4 ppg over calculated @ 11723' md; however, the measure ECD value reduced 0.1 ppg per stand until 1 measured values matched calculated values of 13.75 @ 12106' md. The two values remained close for the next 3 connections to 12393' md. - highest ECD 13.9 ppg EMW. ( 20:00-20: 15 0.25 Service Top Drive. 20: 15-00:00 3.75 Drill w/RSS fl 12297' -- 12480' md. Notes: 1 - PWD Measurements continued to match calculated values. - Some splintered shales across shakers - - bump mud weight to 12 ppg. I - Pumped 25 bbl non-weighted sweep with 8 ppb nut plug and 10 ppb barafibre prior to penetrating SAG River -- no noticeable increase in cuttings when sweep at shaker. I 12/12/02 00:00-00:30 0.50 Drill ahead 8.5" hole from 12480' to Intermediate TD @12486' md. 1 - Top Sag was @ 12449' md (TD- 37' into Sag) 00:30-01 :30 1.00 CBU 1.5 X's. Reciprocate. MW= 12.9 ppg. Shakers fairly clean. 01 :30-04:45 3.25 POOH. PU wt 350 K. SO wt 220 K Ibs. I - Experience tight hole fl 12204' to 12109' md. Wipe. - Backream from 12109' -12015' md (75 K-lbs over). - Continue trip to shoe. At 10750' md (30 K over) through Miluveach. ( 04:45-05 :00 0.25 Monitor well. 05 :00-22:00 17.00 Rlli to 10700'. Tight hole. I Ream @ 80 spm/ 1500 psig and 80 rpm/ 15 K-lbs torque through Miluveach. Tight hole continued through Kingak Reaming- tight hole all the way to bottom. I Pump viscous fiber sweep surface to surface. Sweep came back @ 8200 strokes. Lots of excess. Pump weighted sweep. Less excess on return. I Shales look to be starting to run -- lower Kingak. 22:00-00:00 2.00 Condition MW to 13.1 ppg and working towards weight up to 13.3 ppg. - On bottoms up lots of shale returning. Reciprocating full stand pumping I 570 gpm. 1/17/03 00:00-01 :00 1.00 Continue rig move from NS 18 to NS22. I - Spot up and level rig. ««« ACCEPT RIG AT 0100 HRS ON 1/17/2003 »»» 01:00-04:00 3.00 Bern1 rig, close in cellar, secure stairs, clean up area around NS 18. t Electrician put rig and G & I back on highline. Assigned NS24 as ESD in I cellar. ESD test. I 04:00-05:30 1.50 ND tree and secure on tree-stand in cellar. Install drilling sweep. 05:30-09:30 4.00 PJSM for NU BOPE stack. ( NU BOP's. 09:30-10:00 0.50 Install Roughneck track. - Reposition equipment on floor. Still \vaiting on VLE modification to be I completed. 10:00-11 :00 1.00 RU and Prepare for BOP test. 11:00-19:00 8.00 Pressure Test BOPE stack 250 psig/ 4800 psig. 1 - Test 4" and 5" equipement. ««« AOGCC Rep. John Crisp Witnessed Test »»» 19:00-19:30 0.50 Run wear bushing. 1 19:30-22:00 2.50 Clear and clean floor. VLE in operation. 22:00-23:00 1.00 Rill wi 5" Open-ended DP taking steel displacement of diesel to Trip Tank #1. I 23 :00-00:00 1.00 PJSM for displacement of well bore from diesel to sea water. - SI bag. - Line choke through Gas-buster and back to Trip Tank #1. [ - PT line to G & I suction of disposal pump. - Displace out diesel with sea water charge pressure off the pipe rack. - Control TT level with choke. 1 1/18/03 00:00-03 :00 3.00 Circulate out diesel with Sea Water. -Used charge pressure off the pipe rack & 175 bbls total of sea water to [ displace out the 125 bbls diesel left on suspension. - Reverse circulate 40 bbls sea water to clear the 5" DP. 03 :00-04:30 1.50 P JSM for POOR while monitoring well. ( -POR. 04:30-05:00 0.50 Pressure Test Casing to 4700 psig wi HALCO for 30 mins. 05 :00-05 :30 0.50 PJSM for MU ofBHA#7 (6-1/8" bit). 1 05:30-09:00 3.50 PU BRA #7. - Load source in ADN. - Shallow Test. ( 09:00-13:00 4.00 Rill wi BRA #7 13:00-14:00 1.00 Service Top Drive 14:00-16:00 2.00 Rill wi BRA #7 ( 16:00-18:00 2.00 Slip and cut drilling line. 18:00-19:00 1.00 Pump 100 bbls hi-vis Barazan spacer and chase with sea water. I 19:00-21 :00 2.00 Rill wi BRA #7 into 7" liner. - Wash last stand down before Plugs and Landing Collar. 21 :00-00:00 3.00 Drill out plugs and landing collar. I 1/19/03 00:00-02:00 2.00 Drill out Shoe track and hard cement to old hole TD @ 12486' md. I 02:00-03:00 1.00 Drill 20' of new Sag River formation. Circulatç: M\V in = MW out= 9.1 ppg 03:00-03:30 0.50 Fit to 11.5 ppg EMW. I 03 :30-04:30 1.00 \Vell control Discussion. - LCM pill mixed and ready - Forklift driver has salt pre-staged for brine making. I - Well control board has been updated. 'I", ¡ I I ( ( I ( I I I ( 1 ( I I I I 04:30-21 :00 16.50 Well control Drill. Drill ahead 6-1/8" production hole and TD @ 12886' mdl 111491 tvd - ROP 35 to 80 fph wi final average ROP of 26.3 fph. - Drilling Parameters: Torque 16-17 K wi 85 rpm and 0.5% EP mud lube in system, 303 gpm total flow wi 1900 psi. WOB = 25K. - Final hole inclination 40.55 deg I azimuth: 20.94 deg. - Max gas 680 units in Ivishak - Top Shublick 12632' md! 10953' tvd rkb - Top Ivishak 12730' md! 11028' tvd rkb. - MW dressed out to 9.3 ppg at TD for liner run and trip. CBU: - Pump 30 bbls hi-vis spacer. - Plan to place spacer in 9-5/8". Circulate 6800 strokes. Monitor well. Check trip to 7" shoe: - Hole in good condition. PU Wt off 325 K Ibs. - Continue to pull to 7" liner top to open PBL sub. 21 :00-22:30 1.50 22:30-23:00 0.50 23:00-00:00 1.00 I I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS22 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: TOM MANSFIELD Report Delivered To: KEN LEMLEY Depth (MD) (TVD) 10328 to 10480 ft 9193 to 9314 ft Show Report No, 1 Datefrime: 12/4/2002 Interpretation: Steam still analysis indicates the Kuparuk "C" would produce gas to light condensate, Drilling Mud contained 2% lubricants. No oil odor or sheen was present in cuttings or steam still samples. Sandstone in sample ( 1 0400-1 0450' MD ) had less than 5% yellow fluorescence with a fair yellowiwhite cut fluorescence (cut possibly due to Torq Trim). Traces of pin point dead oil stain were present in the cuttings sample from 10450'. I 1 % Depth 10390 ft Gas x Units 317 Mud Chlorides (ppm) = 18K ---¡:rõWïTñë-------§üëiiõñ------§1i'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 27.2 0.11 27,1 - -- C2 2.82 0.07 = 2.74 - -- C3 1.92 0.12 = 1.81 - - C4 1.76 0.23 = 1.53 - -- C5 1,58 0,29 1.30 - -- --Prõaüëtiõ¡;------------------------------------------------------------------------- Analysis fXlGas nail nwater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios ClIC2 9,9 C1/C3 15,0 C1/C4 17,7 C1/C5 20.9 I ( Depth 10420 ft Gas x Units 703 Mud Chlorides (ppm) = 18K ---Fiõwlfñë-------Süëiiõñ-----=-s1i'õW'.=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 40.0 0.11 = 39.9 - -- C2 5.76 0.07 = 5.69 - -- C3 3.07 0.12 = 2.95 - -- C4 2.30 0.23 = 2.07 - -- C5 1.88 0.29 1.59 --Prõaüëi'ío-ñ------=------=---------------------------------------------- Analysis fXlGas nail nWater nNon-Producible Hydrocarbons 3 % 1 Hydrocarbon Ratios ClIC2 7.0 C1/C3 13,5 C1/C4 19,3 C1/C5 25.1 ( ( Depth 10550 ft Gas x Units 140 Mud Chlorides (ppm) = 181< --~iõwlrñë-------suëiiõñ-----=-§1i'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C111.0 0.11 = 10.9 - -- C2 0.79 0.07 = 0.72 - -- C3 0.79 0,12 0,67 - -- C4 0.98 0.23 = 0.75 - -- C5 1.14 0.29 = 0.85 - -- --Prõ'düëi'iõ¡;------------------------------------------------------------------------- Analysis nGas nail nWater pqNon-Producible Hydrocarbons 4 % ( Hydrocarbon Ratios C1/C2 15.2 C1/C3 16.2 C1/C4 14,6 ClIC5 12.9 I 1 Depth ft Gas x Units Mud Chlorides (ppm) ---¡:fõWïfñë-------§üëiiõñ-----=-s-hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 = 0.0 C2 = 0,00 C3 = 0.00 C4 = 0,00 C5 = 0.00 --Prõaüëi'iõ-ñ------=----- Analysis Hydrocarbon Ratios ClIC2 = ##### ClIC3 =##### C1/C4 =##### C1/C5 =##### ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 . --.--'"------.-.....---.-- -.--------.._--..-.....- -. -.---.-..-----.-.-.- ..-- -----.-..-...-... - ----.-. ..-..-----..-...-- --.-..-..-..-.------------.---.-----.------ ----.-.----------.--- NPH - -. 100.0 - ~".-- -- ~;~=-.;.:?_~=- ~~~t~K~~-~_=~~~~~=~~_____~.-~~~ ---~------- ____..__ n_.......___.._ ____..__._.. _". .n._...___._,._....." ,_,_._,.._........_ _,...__ .. _, ._"".__._,_.._.._"____~ Gas .. ..-- ~_._.__. -_._--~.._...._--_._.-----_._.- _.~.__._._-. --'---"''''-'''--'''-- ~ 10,0:._: --~__~_::..._____.._....____..__.__._.. ~~~~~~-~~ :~~:~~.~==:__:=~:~::.:--= --..--.------------------- -,._,--~_......-._"----- __....__,.______.~...._.__....___"."'_._ __...._.._.._.._. .......,__._ ___..".'.'''h_ ·_"..._,._."R " _,,__ __ _.__.._.____._.__..__._.__n ,___..______.,. . ___,._,.,_._._,_ __.____,_,___, Oil -----.----.- .. .... _ ~.__...'h___ ___.._____.._.__'"_._ ,_______,_._._..._."._.._.._ --------.-.--..- -.---.-----.-----.-..- NPH 1,0 -"-.-..,,..-.- _..~--_.._--- .----..-.----....-.,.-..----..-.---. .__..·.__··.__-.__·"..._...__...hh.._..__hh__..__._____.__..__.__._._.____.._____ C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -_.~.~-_._.._--_._.-.-.----_._.__._--_.._._-_.~.__..-.._---_.~------_._._---_._-_..--_...._-_._----- 1000.0 ----,--.-..--.---"..--" ..- ._..."~,,._-_.._._. ._,... -----,--_._--- NPH __.,,__..___..._...._ .~_..._..._.~..._ .. ._...._,,_.... '''__''0'_'--'-' .___.__._.___. "..__" ,,,.~. ,,__...._ ..___ --.-..---.--..-.- ..._-. -'-""'- ,-.-.-..-- -' -- 100.0 .--.--.-..-...,...--.-- -_._._,---_..__..._.~ Gas --, 10,0 .- ";;-";;;¡;;;"- ......--- ------_.....__."._.~_.__._.~- . . --..--... --..-.---. -.... -_.".__...~._...~,,- _._,.._..,,-,..~ -.....-,..-.---...--.- _~___..__.___,_.__._._ .._.._.....____.ww_.._..._...._.__._.. .____......___._.__,._.._.~_ -.,.-.---...,.-...-..----...---....--.....--. ,-_.._--"....._._--~---_. -----._--_.-_._~.._---- Oil ----.- -....-....-"'--.-....".. ..,-.-".-...-. -..-----,,-,--....--...-.-,,--....-- _..._.__._~_..._----.-... ..,. .~.,...._._._.. .-,..--...-.... -..-.---..-.. ----...---......-----.---- --.-.-..---.-...--..-...,,-..,..-.,.-......-.."'--...-...-..-.----..-..- .... ."..... M._ ...__...,__..._.._~_...___ ..________..._,__+_...__.._.._ ___.____._..._.""__.._....__.. ------. - - - - -, NPH 1,0 w__,.._._._....._"...._......._ I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS22 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY 12460 to 12480 ft 10826 to 10841 ft Show Report No, 2 DatefTime: 12/13/2002 Depth (MD) (TVD) Interpretation: Steam still analysis indicates the Sag River Formation would produce light condensate to oil. Drilling Mud contained 2% lubricants. No oil odor or sheen was present in cuttings or steam still samples. Sandstone in sample ( 124S0-12486' MD) had less than 2% dull yellow/green fluorescence with a slow weak yellowlwhite crush cut fluorescence (cut possibly due to Torq Trim). The sandstone in this sample has a tight argillaceous matrix. I % Depth 12480 ft Gas x Units 135 Mud Chlorides (ppm) = 47 ---FrõiÑlrñ¡-------!;üC'fiõñ------!)li'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 25.9 1.07 = 24.8 - -- C2 3,69 O,6S 3.04 - -- C3 3.75 0.96 = 2.79 - - C4 4.17 1.30 = 2.87 - -- C5 2.66 1.41 = 1.25 - -- --pj='õaüê'iioñ------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 2 1 Hydrocarbon Ratios ClIC2 8,2 C1/C3 8.9 C1/C4 8,7 C1/CS 19.9 I 1 Depth 10420 ft Gas x Units 703 Mud Chlorides (ppm) = 18K ---Frõ,;¡;¡rñ¡-------!;üC'fiõñ-----=-SliõW'.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 = 0.0 C2 = 0.00 C3 = 0.00 C4 = 0.00 CS = 0.00 --pj='õaüê'iíoñ------=------=---------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 % Depth 10S50 ft Gas x Units 140 Mud Chlorides (ppm) = 18K ---Frõwirñ¡-------s-üC'iiõñ-----=-sli'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 0.0 0,00 0.0 - -- 0.0 0.00 = 0.00 - -- 0,0 0.00 0,00 - -- 0.0 0.00 = 0.00 - -- C5 0.0 0.00 = 0.00 - -- --pj='õaüctiõñ------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 4 1 Hydrocarbon Ratios C lIC2 = fI:II### C1/C3 =fI:II### C1/C4 =fI:II### C1/CS = fI#II:II# 1 1 C1 C2 C3 C4 Hydrocarbon Ratios C lIC2 = fI#II:II# C lIC3 = fI#II:II# ClIC4 = fI#II:II# C lICS = fI:##:#:# Depth ft Gas x Units Mud Chlorides (ppm) ---¡:rõ,;¡;¡rñ¡-------!;üëiiõñ-----=-!)-liõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 = 0.0 C2 = 0.00 C3 = 0,00 C4 = 0.00 CS = 0.00 --pj='õaüê'iiõ-ñ------=----- Analysis Gas Oil Hydrocarbon Ratios ClIC2 = fI:##:#:# ClIC3 =fI:##:#:# C 11C4 = fI:##:#:# C lICS = fI#II:II# ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 CS 1000,0 . . - ."-- -'- ---.-- -_..._--~._-- -..,- ---.-- _.--- ---"-."-. NPH - -. 100.0 _._----_..~._..--- - ..... _..,.__..._.~._.." Gas --..--..-."....-..,.-,,-..--.--.-. -.- ..._"_.,,.~._.,,'_...._. ".- 10.0 ;~~i;;-=:_:~~~~~ ~_._--~._._- ---_.._-~_._-_..._...~-- --_._"-------_._._-".~.......-- ._.-_.._-_.._,,--_....~.- _·__·n_··'····_·,·_·_··__·_..··~..·~".. ..._ ...- ,_ -.-. -- , .. Oil _._._-~-_.-..--.,,_.-- ---.-----"..--.. ,-_..,-_...'-'-'- NPH 1 .0 .- -.--,....-....--.---.--.,....-,--- -..--,..--.------~.- .-...-.-----~..-.----. ..,._.._.._-,--_...-_.._._._.._...,_._,_._~_."._-_._..._..---._._-_._-~-_.~._-------,..,-_._-~_..._.._..._- -.. -~._._._-_..__..-_..~-_._._._,. C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 CS ______.__________.__...H.""...__"__._.~__.__ . --.. -" -..,....-.-- -~ 1000,0 .----....-.. ~... ......_~-_._.",....._.~...._....._.- ,-.,."-.--.- .-._-~.,..... -.--,..-----.-- _._..__ _ _"U"__...~.__ .__. ...._._.__ __.~." _. _________._,_.___..._~_, -..... .....- --.----.--.---.--.-.,-.--., ,.,.__._ _._.... ..._~.__.___.._.._O>."~._.~______".__ .....~__.__._,_.,.. ----".~..__.._._---_.~_..--_._.._-_. _._-_._._._._"..-"".---.-~.-,-,,-- -.-''''~---'--.'. ----...-----.-.-.-.-... ._--_._.._._...~._..._--_.._..,--- '''-'._-'--'''-'~'----'-- ------------.- --..-_..-_.._--,,----._._..~-_._.__...~ NPH -' -- 100,0 .H_...'_.__,·".__"_····__··..~~_,,·_,__··· __........___.._...._.._....._...._ .. ~._.._...-... ... ..~"..-._-~. .,- -.'_......... - -~-_.__.,..__._~_....__.._...~.,,'~_.....~.,.__...__....--.....,-.-.-.. -_._----_._---_._-,._..__._._-_.__._--~--- Gas ----_...._~-_.._-_.- -.---.-.---'-.- ,-----.-....--....----. .-:--:.:..::--=-:: -.;;;.._;;;;;-.,-_.__._---.'!!".'_~-~-~._-_._. 10.0 ~.._-~....,_.---,-..-....,.,--,........_,...._..._- ..-..--.......-...---.,.,.,-..--..-..-.-.-- .-..,-.......-.--.--...---.....--...,.-.-.-- -_.,--_._----,-,_._".__.~ .--..--.------.-..--.- ._~.__...--.-_.~_._-------_.- --,--_._~-,-_._---_.,-_..._--,._.__. ---.-.-'''--..'--'-'.-..--.-...--.'''' .._.-..._-----,-_._.....--_.._.-.-.~,,,.,- --.....--.-..---....-.....---.-- '-..-.- Oil ....-.---,-----.---..- .,----.------,.-.-.--... -.----."...--,..--....,--- -_._.._---~,_.-....._...__.._._...._....- -..------.-.".--.,-.--.. ..~.,_....-.. ..~.~._.....-_. ..._-~.._._._...~ ..~,.,_.._..,...- --.---......--,-...--..--.-......-..-..-.--.- --,....---..-.-.----...- .----,..-.-.---..---.---"--."- -----.-.---.---.---, ,----,------_._..,...._~ ,,----.--...--.-- .....--.--..-.'.-.---.. NPH 1.0 .. ..-..__.-_.._-_..._..._-.--_.-----_.__.._._----_.~._~---.---. -_._...._._..._....._.,.__....."....~...- I sperry-sun Well Name: NORTHST AR NS22 Depth (MD) 12550 to 1276Q ft Location: NORTHST AR AREA (1VD) 10894 to 11053 ft DRILLING SERVICES Operator: BP EXPLORATION ALASKA Show Report No, 3 Show Report Report Prepared By: REG WILSON DatefTime: 1/20/2003 Report Delivered To: KEN LEMLEY I I I I ( 1 1 Interpretation: Steam still analysis indicates the Sag River Formation would produce light condensate to oil. Drilling Mud contained 1,5% lubricants. Sandstone in sample ( 12550' MD ) had less than 10% dull yellow/green fluorescence with a slow weak yellowlwhite crush cut fluoresence. This section of the Ivishak formation would produce oil. The conglomerate in samples (12725-12760' MD) had -20% bright yellow fluorescence, with a slow dull/green cut fluorescence 1 % C1 C2 Hydrocarbon Ratios C1 C1 C1 - - C3 C4 C5 Depth 12550 ft Gas x Units 400 Mud Chlorides (ppm) = 18 ---FrõWirñë-------~üciiõñ------~hõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 6.0 0.45 = 5.6 - -- C2 0,90 0,10 0.80 - -- C3 0.70 0.07 = 0.62 C4 0.47 0.06 = 0.41 - -- C5 0.26 0.05 = 0.22 - -- --PrõaüCiiõñ------------------------------------------------------------------------- Analysis fX1Gas fX10il nWater nNon-producible Hydrocarbons 2 % Depth 12725 ft Gas x Units 180 Mud Chlorides (ppm) = 18K --Fiõwlrñë-------~üciiõ-ñ-----=-S-hõy¡:::"--------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 7.6 0.45 = 7.2 - -- 1.1 O~10 = 1.04 1.0 0.07 = 0.91 - -- 0.8 0.06 = 0.72 - - C5 0.5 0.05 = 0.47 - - --PrõaüCiiÕñ------------------------------------------------------------------------- Analysis nGas pqOil nwater nNon-Producible Hydrocarbons 3 % Depth 12750 ft Gas x Units 200 Mud Chlorides (ppm) = 18K ---FiõWirñë-------~üciiõñ-----=-s1i'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 8,8 0.45 8.4 - -- 1.4 0,10 1.34 - -- 1.2 0.07 = 1.09 - -- 1.0 0.06 = 0.97 - - C5 0.8 0.05 = 0.75 - -- --Prõaüëi'iõñ------------------------------------------------------------------------- Analysis nGas pqOil nwater pqNon-Producible Hydrocarbons 4 % Depth 12760 ft Gas x Units 160 Mud Chlorides (ppm) 18K ---Fiõwlrñë-------§üciiõñ-----=-ShÕy¡----------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 9~ 7 0.45 = 9.2 - - C2 1.46 0.10 = 1.36 - - C3 1.21 0,07 1.14 - -- C4 1.15 0.06 = 1.09 C5 1.01 0,05 0.96 -lPrõaüCiiõ-ñ------~----- Analysis Gas Oil C1 C2 C3 C4 C1 C2 C3 C4 ~--_._-,--_.~-~- . Hydrocarbon Ratios C1/C2 7,0 C1/C3 8,9 ClIC4 13,5 ClIC5 25,8 1000.0 . _ ~__ .uo _~_.__._ _ - --.-----.. .-. ,_.... NPH 100.0 - -. --- -_...._--,,_._--_..~.-..- -~_._"'.~._.-._._...__._.- _.._,- -- --------.---"".,---"...,.---..- Gas --,,---_._.._~._._._.._-_..__._....._... -.--.,-.---.-...-.---------- ._--_....-..".._..----".._.~._. ..---- Hydrocarbon Ratios ClIC2 6.9 C1/C3 7.9 C1/C4 9.9 C1/C5 15,2 10.0···· I[_~~_~----,.,'-,.._------_._-_._,.._---_....__._--_._.._....____ ._...."--,.._~.,,.......-.._-- ---..- . .....--.._._-'"-~.,,,.,,_...- ...._.~-,_..- ._-~..._,,_..._..,,----- Oil ---.-,."-.-.--.-,.,-.- --.-. ..... .."'-..-..-..-- .. ___._"M____....._M.._ '._"_"____'_"'_"'h. NPH 1 ,0 .. "..,....."..-.-.,.." ..,,--...-.-..- .,.....,.".,.--.-.-....,..,........--. ..._,. .__..,__._____.M...__..__n . ..---"-'.--'-.--.-..'-"."-'.-.-.-- .._...._____....._..___.____......_......._._.___._..__M______'_'M' C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 --......--....--..-.-,-.------. Hydrocarbon Ratios C1/C2 6.3 C1/C3 7,7 C1/C4 8,6 C1/C5 11,1 1000.0 -_..~-,-,-,......- ..__..,.,,'_......_----_.__._.._._.~..,~-------_... ~.... -,,-...----.-.-,--.. ~-_.._..__..._---_.....- -."..-,..--.---.. -_._._~._._-~. -_._._._,-'....~~.,._- .-'-. ...,..-.-,,- ..._-_.,_...._...."._-'".."'--_.~,-_.~,-,.- .-.-.... ..--- ..... .... ."..~.__..._--- -".----,..---.-.......,--...-.......-- -_.._"..~....__.._.."--"".._...,.....~. -.....-...- ..".."'''".....""....,,.~._...._-.. ..-..."......_..."--""--~..__.._...~..._-,,- ..-......-.-..---. NPH _" "'_'".~__......h'_____.___~._...._._ ..._._.__... _.. _...____M~._ ..-"-...- --.._~..,-_.-_...-~"-'-'--" -' -- 100,0 ... ..... ..._.~.....- ~_...._....._.. ...._-""_.._.._......-~.._~.....-. .-. "... .-.- ..__.~...--.._-"._...,,_..__._--_.- _____._._.,__..._,,_h..'...._ .,~._,________'__...h..._._'.,,··_·______ .__."_M._._'_.··_·_·__"_" _____,.._ ,.".__ _."._._~...~ ...- ...,..- ..... ..... - -..". ..~. -.---. -.- .,.."-... ..-.--...- Gas __...___..__.___~._..,._.._.__.___~.____.__~._M.____ ._._._____,_.,.______ ----~ ~- ~~ -- --- - -:--...- ----;.--;.. -~ -~~" ....-...-.... Hydrocarbon Ratios C1/C2 6.8 ClIC3 8,1 ClIC4 8,5 C1/C5 9,6 10.0 ~~~~~~~~~===:.~~.~~:~:~~~::!=.:==:~==~ Oil .._..._..._,.__.__..,.,__.,_..____..____._.._...._.._..'..... ..m__"._.'.'._..."...".."._'_'_··· ...,__.M"~"_'_"'_·_._'_· ._,~_._..._.....___._....._..____~.."_, -.-. .- -_..._..._.~.- ---. "..."...._~..,,-~-_..- .". ....--.--- -.-.-----. ".--...---.-.-- -...".-.--..---.---- ---......-~-_._,,_..- NPH 1,0 .....--.....--."-,. --...__..-.."...-_.~_...._.......~ .....-..-,. '_"--~"-'-'----'-'-- ---------------------------------------------- r sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS22 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY Depth (MD) (TVD) 12785 to 1285Q ft 11072 to 11121 ft Show Report No. 4 DatefTime: 1/20/2002 I Interpretation: Steam still analysis indicates this section of the Ivishak Formation would produce oil. Drilling Mud contained 1,5% lubricants. No oil odor or sheen was present in cuttings or steam still samples. Conglomerate in sample ( 12785-12850' MD) had - 20% bright yellow fluorescence with a slow streaming milky yellow cut fluorescence. % I Depth 12785 ft Gas x Units 220 Mud Chlorides (ppm) = 18K ---Fiõwirñ¡-------šüciiõñ------š-h'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 11.3 0.45 = 10.9 - -- C2 1.59 0.10 = 1 .49 - -- C3 1.17 0.07 = 1.09 - - C4 0.92 0.06 = 0.86 - -- C5 0.66 0.05 = 0.61 --Prõaüë'iiõñ------=------=---------------------------------------------- Analysis nGas JX)0il nWater nNon-Producible Hydrocarbons 2 % Depth 12790 ft Gas x Units 281 Mud Chlorides (ppm) = 18K ---¡:rõwliñ¡-------šüëüõñ-----=-ŠhõW'.:=:..-------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 19.2 0.45 = 18.7 - -- 2.7 0.10 = 2.6 - -- 2.1 0.07 = 2.1 - -- 1.8 0.06 = 1.7 - -- C5 1.3 0.05 = 1.3 - -- --Prõdüëi¡õ-ñ------------------------------------------------------------------------- Analysis nGas pqOil nWater nNon-prOducible Hydrocarbons 3 % Depth 12800 ft Gas x Units 243 Mud Chlorides (ppm) = 18K ---¡:rõWirñ¡-------šüëtlõñ-----~hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 13,6 0.45 13.1 - -- 2.1 0.10 = 2.02 - -- 1.6 0.07 = 1.49 - -- 1,3 0,06 1,23 - -- C5 1.0 0.05 = 0.94 - -- --proaüëi¡õ-ñ------------------------------------------------------------------------- Analysis nGas pqOil nWater pqNon-PrOducible Hydrocarbons 4 % Depth 12850 ft Gas x Units 150 Mud Chlorides (ppm) 18K ---FrõWirñ¡-------šüëiiõñ-----=-Š-h'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 2.2 0.45 = 1.7 - -- C2 0.35 0.10 = 0.25 - -- C3 0.33 0.07 = 0.26 - -- C4 0.33 0,06 0.27 - -- C5 0.30 0.05 = 0.25 - - --Prõaüë'i¡õ-ñ------------------ Analysis Hydrocarbon Ratios C1/C2 7,3 ClIC3 9,9 C1/C4 12,6 C1/C5 17,9 1 I C1 C2 C3 C4 Hydrocarbon Ratios C1/C2 7.3 ClIC3 9.0 C1/C4 10,8 C1/C5 15,0 ( I I Hydrocarbon Ratios ClIC2 6,5 C1/C3 8,8 C1/C4 10,7 ClIC5 14,0 C1 C2 C3 C4 Hydrocarbon Ratios ClIC2 6.9 C1/C3 6,7 C1/C4 6,5 C1/C5 6.9 ---------------------------------------------- 1000.0 NPH 100,0 Gas 10,0·· .:......... NPH 1.0 .. 1000.0 NPH 100.0 Gas C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 - ~ --.,-.--......-..- 0- ~_. _'_'__.__..",__ --"- -." --".~--_. -_._-",,- -'--"--~~-"--- --.".-.- _._,-,--- _ ~..._h"__,.___.._"~._.._____.__ .__._.__,_,____..___~ .____ ___._____"'_. _..nm_........____...._ - -. ,,'n___ "_.u.'_ ",,,____. --- ..--..."""'.-....----.-.-- ------ _,_"n __...,._..~..,._'"'.._.~_"._,.,___ .._...___,__'..__~,_.._~.~.__"._,.__ Oil .-...-.,--..,.-.....-".- ..-.""-....--.-....--".. ._.__..____~___..,_,. ________··________····..___.'M__. .-".....__._,-_.,....._..._-,--,-_._.~.....~....-.-._---.-- .--..-------....-..----.-...-...-,----.-.-.....,..-.--....--.--...-. C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 _....._..~_.----_.._.~.._----_._._~_.__.~-,-,_.._~..._._- _.~...._--_.~._,,-----_._....._._.-_._--~--~.~.._._._-----...-- - ,-_....._.~._......_.....__...._. .,. ..-.-.-.. ._~_.."~........__.,~-~_."_._-.. .-..---.--- ......_-.__.<-~.~-~-,,_..,,_._-_._,.... ._--,_._,--.~_....~,.~-,_..._-_._._, ,-_._._-~_.._'.-,..."...,,_...._,.__....". .._...------"......._.._~---_._--_._.. ---..-,-.---- __..~.._~._h'__."'__~...__...__".·,.._._ __.._._._,_.~__._.._'.____._.._......._.__,,,.~_....____._'''_''_~_'__.'' ... .... _~.. . _.... ..,~". ".._._'"_,_..._,,~._u__._._~.,.._"'._,_ ...."_~",,._''',...____..,.....~_.._..__.__~ "_'_"'M'~'_' __"___"'_'_"__",_",,_ ,,_..___~~_..~_..__._,,_'...,.~____ ...---.....'''.'''...-.----...-...''''....-.-.- -' -- _...'""'..~.__._..._._._~.'"_.....- .~-._._~. - --_.~--_._.~_._.....__...._. .- .----...-.--.-....... .-"""- .-.__....-......._~...~...,. .~._,....._~__ h"""~ _, U__'" _~_.. .__ ___ ._." _..__.. .__ .___.____ _.......-- ;;;;-"-'-'"'''''--'---'-~-''~--~~'''~''' .....--. .-. 10.0 Oil ~:~.,--~~~,...__.,....- .-...-.. NPH 1.0 -"--'--."-'.--..-.-- . ...... .n. ,,_. __ .. . _.__..._ '___'__.'M'M --...----...- -..----. _..-.-"~._.._-,,..-. --.--....-...-..--.-- ~--,-_..._..._-. -.---.-, _.~.-----_.- __~.__...._.__~.__u__ ._.__.__._.....__..~R"_~__._ _R._.._._._.~._~__.._...__.__~_ * 10000 units = 100% Gas I n Air , . ' , ~,.I>it.l,~ I} ~l Wi ~~? , .~~ ~1, - ..\, , ,\ ,~", -:.. 'Y'<,~;;:i!l¡" Logging Engineer: Mark lindloff / Doug Wilson 24 hr Recê 30 Feet. , ~ ,..~., Move Rig to Well #21, N/U Riser, P/U BHA #1, Clean out conductor to 201', Drill on Gyroing every .~:..:";: ":,:', % lithology Sst Sltst Sh :;.\.:<.':..,:, ", r~':'" \-~,.f.;<: ;..~';"',I~''''>~~~~f.,~f/;~,,~ :r1~l1j.~\·:';:··:i.~ .....: 1;1/:7'~',',i'~ ::':::'::r' .<.:;;, .~. "l"'~~':' "," 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz. Description of fillings: predominately small slivers, some small chunks, some curley Os after Gas during before after to to to to I ft ft ft ppg ppg ppg Drilling Breaks Drill Rate during before Depth "w'O'· '. '".,:",' ", ·'._;,.¡:!,i~:~;¡!ti(I-wlt.t.',~:'~'·:::,:",t,~·:!l;;'"ØU;;,.~;, '1:':.",.,,": ',' "'~ "., ,;~titi;i~i":,,·~''t\_'~'~~-. y ',:"·;:,·;:.,i";·.'."'!:Ji.;"/~;',)·~t';;~"~<':;.~:. h:1~:"¡¡'~'~~;'1:U' ~':::"" ' 1 !: ¡~t"~~¿"1 "";":I,,;:,-.'~~'t<:¡:;~~::¡'~i1\l:?~"f~~if;i,iit4~_~~~·f~~~'W:;&'$:;¡é:b\¡.!"'~;:":;;~1~~;1r~#~~~',~~~*t*,";f?~-;"~:~ßrw.£(~.;-~~~:;::w,MK~¡:':'::,~!2¡~~{¡.?>'-~~!·')'?'~'":' ~t,'""" ,"", ,:',;1,', I ",I,:. eonnection Gas and Mud Cut , ~I... ',..~ ft _ units ppg ft units .. .. ft _ units ppg ft units >: ft units ppg ft units ppg ppg ppg units units units %LCM 1 Trip Depth: ft Trip Gas: NA Mud Cut: Short Trip Depth ft Short Trip Gas: Mud Cut: Tight Spots: to to to ~¥I\W~!%'mW~~;_"'~*!'1!i¡;iI*Jï.&~~.I\~w~*~m~~ Current Lithology: % % SLTST % SS % ppg CI: 17500 ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft "~' : 'r' "~';""'~\I"", '.', . '1',~o}..:¡.' :f. .,'.,,~, :.' >".;." ;; ,~t·'.:.'_: \;~.~,:...' ....~: .~.,..' ;. .: ", :-'.,~;, . ',f, '.~~,~", '.;.. . . .~:}"" .' '.~':;~ 1.0310 270 TFA: -- Footage for Bit Run 1 X 12 -- 3 Jets: 3 X 20 -- Total Revs on Bit: gpm gpm fpm fpm --- .'''~~~·Ir~·..\~ :':'î~::·t'IÍ~.(>.'i:""· :u~~,r'" ~','," I~ ',),.<,-('..', , , " '~li..I,::'" ."~ . . .~<'"; . ~ "'\>~~~~' , ' 1 Visc ~secs APlfilt ~ml HTHP _ Mud WtatMax Gas ~ppg PV 24 cP YI 57 Ibs/1 00ft2 Gel~ 18 / 21 / 22 Ibsi100ft2 pH 8,5 Sd 0.25 % 1.0 MXC-1 Bit Size: o Hrs. On Bit: I 1 Type: 2-5 RPM: Bit No,: Wt On Bit: 16" 8,80 ppg 8.80 ppg Mud Wt In Mud Wt Out ( 520 41 66 Pump and Flow Data ò2 spm DH flow 61 spm Total flow spm A V @ DP 410 psi AV @ DC 24 hr Avg 24 hr Max ft/hr 307 ft/hr ( 492 ft/hr @ 237 ) Pump 1 units 4 unit~ ( 6 units @ 227 ) Pump 2 Deg F ( 50 deg F @ 270 ) Pump 3 Pump Pres I' 1 11/21/2002 270 70 Drilling/Gyroing Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Gas* Temp Out Current o 3 50 R.O,P, Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I DRILLING SERVICES sper'r'V- SUI' * 10000 units = 100% Gas In Air , " .. . " " Logging Engineer: Mark Lindloff / Doug Wilson Top of Permafrost 1195' MO, 1190' TVO Base of Permafrost 1625' MO, 1564' TVO 24 hr Recí Continue to drill F/270 T/51 0, Gyroing every 30 ft. Pooh for BHA #2, RIH and continue to drill F/510 T/1557. Currently drilling ahead. . '. '~"~"';',-~:.:~::?'~ ,\,,:.",' .1~,;':':'.;~I\.:·~:í~":i~:;".:::'\'," .... r .J~",,'~"·'·....~'1·· % Lithology Sst Sltst Sh ~ ":~'~',".,..,.,: .,~~.-:;"~~"'I,;"':' ~.'_.~, :':~'I~.:~.(:- ¡" .....~:.. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz. Description of fillings: predominately small slivers. some small chunks, some curley Qs after Gas during before after Drill Rate during before to to to to Depth I Drilling Breaks units units units I ." k;¡.'?'. 'r ~~~j, ',:d':~~;~'-',,,¡,,· ~p:~.;&:i.i"~""\-:'''~Ä-¡''(,: ì ..~:' ~..¡;::. >' ·;:·;;'t._~~~r.~~;t1.;¿~,..t:; ~ Ii> ~1.~~",,~;'''':~~'&.<';',t<ì,;f¡-t.,~:~:k.::;U;: ~;;<\:.;:".Ù"î~";r.:~·,~,:¡,;tìtb;,.1..:";··.'~ "f,~;)Ì. ~:j~:t''''' . r .":~'.' 'lJ,æ", I ppg ppg ppg units units units ,....... . '_,,, _,....,..l';,i!...'....'...'.... "'.';. ..:.' :-..."', '".",,"..' '..:) 17500 ppm ;. ppm ~ :~ ft 'j:; ,J~ , 0,1 LCM ~:; .0 _ \\':\:' ., ,',' .-'¡'.;,.'·,..,'i,o;,:;,· ,.....::.,'~..I:.".,\J? "" " '... . '. . '. t·t ~ " ;[' ~~.: .~'. '.... 'f~"'+1I" ' ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ft units ft units ppg ppg ppg ft ft ft I % SS ;";:-:,:II'·~ ¡.: '''''"f.:'\f1.~~'.~~- ~'·.I\I..L:."I..-..'GI,~_'1ts~~:~.tY,'.t·..,;','~ ~i~.r¡f·j'..:.· ...... ~,~'I.... ;3~~" -... .,,~:oI . '.~ ~~y.F\~~~!7,~41.¡1.""~I~:!'..... '~'.. .. ~.r...~I,~<!...to~.,~.~,~1.".~f~ì;M~ .:~~~..~\!r,f;:';~f~~,~~(f~~~~..ør.r~~·...:~·:-: . ~~. _.... I '.-" .' Current Lithology: I ',..~'~ .,~.~~"¡".,:",,~.,:,,,.. .:'··:.'L·' '. ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: % % SL TST .... I': 'j¡. ~ ..¡,...;.: ';i. '. ~ .... ,.... ~ '. '!.-' .. . ~..:. '. to ......,' ".-vi~..:·· .'::".' .",,' :·....s.·.·.,I'..'I·..··~·,·:·1 .".J',I·.."'·.:.'.-·,:.;~..h·..·'.'.~ ,... .. .., I, , ~.. ~: .... '. '. ' Mud Cut: Mud Cut: to NA ....,·t .~.;>~}...~):~;..,";';., ';. ,~",~;.:,':. ~/,~;.:- ::,1'~ ')". ~::~"'-'f ¡,\':;; ,"."~ ""',"'>,~',.·~;11: . 1. 0.31 0 1,557 1 X 12 TFA: ---- 57 Footage for Bit Run Jets: 3 X 20 -- Total Revs on Bit: % to Trip Gas: Short Trip Gas: ft ft Trip Depth: Short Trip Depth Tight Spots: ·f 10.0 . \:.; ~ '~.' '::",,:;~'¡'~I'.;' ~',~~~ ! ~ ~ ¡~ ,\ :~i ::;, t :...:.:.: .~~> ..~,..;: :.~' ."~~ 'I~ .;.'. ~. ~-, -'..' ~.~ ~"I:'':' .~~~:;~< ~,-::,,·;i.~~ ,~-i~..~~:·,:7,~·~'t.~'~; ~~:.~,~. ,,'. . ":'4~'~ ,,¡ .:.:¡ 'f r;v ',~'. ........ 16" Bit Size: _ Hrs. On Bit: Type: RPM: --- MXC-1 o Visc ~ sees API filt ~ ml HTHP _ Mud Wt at Max Gas ~ppg PV 19 eP YI 45 Ibs/100ft2 Gels 21 / 28 / 31 Ibs/100ft2 pH 8,5 Sd 2 % I gpm gpm fpm fpm 719 56 91 Pump and Flow Data 85 spm DH flow 85 spm Total flow spm AV @ DP ~ psi AV@ DC Pump 1 Pump 2 Pump 3 Pump Pres 2 11/22/2002 1,557 1 ,487 Drilling/Gyroing Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1079 453 1564 24 hr Max ft/hr @ units @ d eg F @ BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 9,00 ppg 9.00 ppg 773 18 52 24 hr Avg 190 ft/hr ( 4 unit~ ( ( fUhr units Deg F 1 40 Mud Wt In Mud Wt Out Current R.O,P. 150 Gas· 18 Temp Out 52 I Mudlogger's Morning Report I Customer: Well: Area: Lease: Rig: Job No.: sper'r'v-sun DRILLING SERVIC::ES J," * 1 0000 units = 1 00% Gas I n Air Logging Engineer: Mark Lindloff / Doug Wilson Top of SV6 3347' MO, 3091' TVO Top of SV5t 3655' MO, 3368' TVO ":,.,:,~,.:;.,~"...", :,;'.::',.~,~':',";' '" Continue to drill F/1557 T/3725, Circulate Hole Clean. Currently POOH, No problems at present time. ,I;,."')... . , iI' ppg ppg ppg units units units .;~ .,'.... '~ " .~ . ...:)... '. ~:' :, \,', . .":',~~'-., 24 hr Reci . (\ ' . .', .. ~ ~ ': ". . ~ . "';, .: ' ';. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz. Description of fillings: predominately small slivers, some small chunks, some curley Os . ;."i' .,',.... \:~. . ... . I. . I.' '" . .~ ~~"!. ..~"-·:~...:i:.~~.;:..~.\·' ..' ···.'}·~·~~::~~I~,.tllo·;.~~~I;t~~;;.I/~ '''_..~...~J.'..;..~' _~" 1 . I. ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft _ units _ ppg ft units ppg .....,~ :'::~"/H~.~.~ ~.",1:.1~~:\1:~'~':'" ',::~" to to to to I I ;' "!¡¡ .~'... ,_1..r\~\;¡.,;",. ',,\.'''·r'¡;¡~~''''~ 't'-'.> .~. -. Y' "II'., " ,;,.. i' . ., -~ ,. ..'..ì,'_~. ('iWf.!<,..J··:ë~HJIi!"·~$""·Þ'''¡~;';'114ðJ!W "\1!'·",h.<'~ 0"· ...(t'llo!'M" .'t-llli'¡~"'" ')\' ,.,.,::;" ~,~~.,~ ,¡ ,:,.~ "", , ,,~- ~"'>'~I:.1':c fl' . ....".. -..' ,... , .~.. '", ~"..",.~ . .., ., ," '... ." ", -.. .." .,. . ···f.·'··..· ..... '-1'! Drilling Breaks 'i' Gas % Lithology , after before during after Sst Sltst Sh i¡?, i:~ i~, ...¡ ~ i\ ~ti ( .:~ Drill Rate during before 1 Depth ppg ppg ppg units units units ft ft ft -1~: ~i,{ 17500 ppm '~ 1~K ppm .~~. ft .~ ';'~!1".¡~t'j.;;&i~>^:·}:·>'::';'i-'.'f.~.'),~'t~~'~~:w.~¡;.t::::~W(;""i. ;"1>;'';; ~;~';?ffé~~1J;,'í'I:';'¡;'::d"';:;: ':, i:. :';"~!:I :':'<,:,'i'"~,~;P;.~!·~;"~t\;:<';tr.:;' ¡-:;""'~"j ~~"".;'.'l"';",~.:'·~·",J~'::~;:V: )':':"~~'i;t SH % SL TST % SST % %LCM t. .'~' r,",;:;;~~·iPíj¡;r':iIi:~~::M.'i~~·.._t.: ..':.' .:~,·.....'utir."ö!'~:~~:;~~~~t·...'f., ,;·i¡'!>.f'.í',"*~_~¡~.';,';~~'\'i.'k~n'i~,1,:i'$;:I~.'}P>Ïf."r.::;,,·;;I,;:.JK'.·,à~~~.!I\'~ .'~', rìïJ'..';,-, " i.,~~'·:·.'f>', "', ,." ): .f.' I~'+'" ,.., _,'/I ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to NA '. . 1 ~. .' . 1.0310 3.725 1 X 12 TF A: ---- 155 Footage for Bit Run Jets: 3 X 20 -- Total Revs on Bit: I Trip Depth: Short Trip Depth Tight Spots: to I Current Lithology: % to Trip Gas: Short Trip Gas: ft ft ., -;¡o. .'j 16" 20,0 Bit Size: Hrs, On Bit: MXC-1 o Type: RPM: o Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Vise ~ secs API filt ~ ml HTHP _ Mud Wt at Max Gas ~ ppg PV 15 cP YI 35 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8,8 Sd 2 % 9,20 ppg 9.20 ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data RO,P, 0 ftJhr 236 ftJhr ( 994 ft/hr @ 2166 ) Pump 1 0 spm DH flow gpm - Gas* 0 units 15 unit~ ( 35 units @ 2824 ) Pump 2 0 spm Total flow 0 gpm - Temp Out 64 Deg F ( 64 deg F @ 3725 ) Pump 3 spmAV@DP 0 fpm Pump Pres 0 psi AV @ DC 0 fpm 3 11/23/2002 3.725 2,168 POOH Kidd 1 Clump I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I sperry-sun DR I LL IN G 5 E R V I c:: e 5 * 10000 units = 100% Gas In Air . ., '.~ ~"''';.1:~ ':..~,':. \.....:'>. 0..:....' Logging Engineer: Mark Lindloff I Doug Wilson 24 hr Reci Displace Well with Brine Solution and Deise/. Nipple down Riser. Decision was made to stay on NS22 and drill intermediate hole do to the lack of ice. Nippled up BOP's ..,' -:':," .....'~~~ ;.... ... ~'t, : ,',).:~t·,} .....<~..,.~,.:..I~. -:;, 'J:~·"'.~.\f~~.:,: ~"':7':: "I::..':~'; ;~:..< (~ . -. ~','!rl,"'1I~~t1':'~~~7J '."-'il"~,~~~\f~;;: ,~,;.~."j'~ :~;:~ J" ;,\::~.....".,,~ :~¿~~'-J I.. '," .'~J.',:/ ", . '1' :~~1':.':· . :'.~ ,,':: :\:' t: I~~t¡" ,,~,~;; ~.<. -:::~~ ;~:.j 1.7.1."_': ':':"J.'" J.........,;;>~ -:: .. :.~. % Lithology Sst Sltst Sh ppg ppg ppg units units units 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz. Description of fillings: predominately small slivers, some small chunks, some curley Os ~.:;~~~~~~,.~ .'.~' :rrtJ~r".{';' ~~\: :\lr~ .": 1 . "'. \ ~:~~'..~:,~'-':~' .'~~.r ~:~~15;~~~.!~:~·: .~~::;:('1~!.'~ :::~i.I·.;.~..f ,:'~'~_~~'~":~:'~'-'~'~ ;·,~.·I: . qr~~: ::.~ :: .' .~.~,~~~.~ '¡,~:. :... ::.: , ~ ~,G ;'{'. ,~.:" after Gas during before after to to to to I ,i·¡;;:·.t·'?ï1J1~..;~,;:r~~~~.¡r.'oÍ'~¥H~b.fj;.I~)t~"!I"":'~::'i't 'ii':;,;;'&¡ ,,¡;,-:,'~;:·'j<l'~;'J.¡t:r~~,.~~~'14.~,h"'''!~I~¡-'~,;;;l~:'~.:'í~:o\',r,:.:1·-"ìf.~~~~~''''·." i, ~"~,' ;;:;,:,~ ,~.;¡:2..:~«è·'" Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg Drill Rate during before Depth ppg ppg ppg I units units units ft ft ft I ~óLCM . 'J'''~_~,i~~~~'~ ','=. ·,~J'i~¡~·~~';.·~t1i-,,~.t'f,o;7t?..,Sr~~~~'I!~-;'~: ",~,ÀI'~' ;':)J~:/}lr ~.,~;fo·..ry ·t',~"1.~"fh3.4fi~~~""'J1.;;'· 4·;:"~*-::"'.~·~~ R\ I;'~:" ,"~~;.t..~: .~, :'.:~ ,í~:·t,:":~~'~\"':lt'"~\t¡t~·· .~,- 'I~', ,; ,~~,,~YJ~'~~_.:o.f1.s""; ~r':;'I,~I"..:~\...~~""" :\It'~ ~ r ., I, .': :¡.. SH % Current Lithology: ',I' I % /)/0 !>¡'Q SL TST SST :;::}~t~¡1':i¡';';;.?~"'/'~~':'t~:'f:~':'¡ .;. '::;::, ~;~f3~~'_'Y; ::-;~;'~f;*~~p:r~, ~::I.'}1..~':,:'·~".',.\, ~.I ~'~"I:' .\.. ' ppg CI: 121000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Mud Cut: Mud Cut: to NA o 0,0 o o ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: '~"'''~.~;f.' ¡"~,.' < \,:' ;~1;~;<r¡.~i""-.:'1.'~'~I:1r.. '~,:~,~n~:' ·;~~;:t/. ~":'~':'~'~!" ~.~:: -,:, .~...:-:',<',,,~,;..;,,.~'':~~':,I.'':If~~~'I. ':;;,~ ,~~',~ ..<'~.~. ':. ': ~ ~~. '/. ',..... 4':. _~.:.. . .' ' . ,'. ~'.i..,<:,'~: :~, )~:.,':~:. ".:, ¡":'\', ,.:' ':':!r'~:' 'I .':'~ :~:~'~'/::: ~'. ' 0.0000 o o X 0 TF A: ---- a Footage for Bit Run Jets: 0 X 0 -- Total Revs on Bit: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ftlhr ( 0 ftlhr @ 0 ) Pump 1 0 spm DH flow gpm Gas* 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow 0 gpm Temp Out 40 Deg F ( 60 deg F @ ) Pump 3 spm A V @ DP 0 fpm - Pump Pres 0 psi AV @ DC 0 fpm r. II Mud Wt In 9.50 ppg Vise 28 secs API filt ml HTHP Mud Wt at Max Gas ppg - - - Mud Wt Out 9,50 ppg PV 1 cP YI Ibs/100ft2 Gel~ I I I bSi 1 00ft2 pH 7.7 Sd 0 % - - - 5 11/25/2002 3,725 o N/U BOP's Kidd 1 Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Bit Size: Hrs. On Bit: o o Type: RPM: I I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I D A I LL IN G 5 e A v I c:: e 5 sper'r'Y- sun r spe.....,.....,y- sun o A I LL IN G 5 E A V I c: E 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I r I 1 Current o o 40 R.Q,P. Gas· Temp Out Mud Wt In Mud Wt Out " . . ~ r ftlhr units Deg F 24 hr Avg o ftlhr ( o unit~ ( ( o o 60 BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 24 hr Max ftlhr @ units @ deg F @ API filt Ibs/100ft2 ml Gel~ --- HTHP / Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: o o Pump 1 Pump 2 Pump 3 Pump Pres 5 11/25/2002 3,725 o N/U BOP's Kidd 1 Clump Pump and Flow Data o spm DH flow o spm Total flow spm AV @ DP o psi AV @ DC Mud Wt at Max Gas Ibs/100ft2 pH 7,7 Sd o 0.0 Jets: 0 X 0 -- Total Revs on Bit: .. "".. " .., .. '" ~.":':( -'," .~~."' ~;;;'~ " ~,~¥>';\, ,.:;i:¢"i~/~:~~·:···' ~:,;.' ',''¿. .,..~. :", '.: ,:,,;,_~~~:~, '·..;v'..·.-~~ ...W:1.í,·...···{,~¥>t¡..,~~~··¡.;,·t~$..:..~·~:i;~.· ::>.;.;".~. .:." , units units units ppg ppg ppg Trip Depth: Short Trip Depth Tight Spots: Current Lithology: 9,50 ppg 9,50 ppg Visc 28 secs PV 1 cP YI ft Trip Gas: NA Mud Cut: ft Short Trip Gas: Mud Cut: to to to % SH % SLTST % SST before Drill Rate during o o Type: RPM: o o Bit Size: Hrs. On Bit: '"I¡¡."I:. ,"" ~ ,~. hJ~,~"'~. ~11.~~~,~.,··.'.)..1p·~~J.\¡~·.¡.,t~....·~··~.'....·11~.\.~1.V,~.'~~~"l~r^ _ ,'.11'.. .::,,' ..v<~-r:~':-t.~~~ ,tt',_j.~~~/~~,~.i,:",:...!~.!1'.'-,~"" ''-:!. r ,,-.Jit" ~.~ I ":', ¡'~i ~~, I ~I ,~~ <'i ( ft ft ft Depth to to to to ,r.I';". Connection Gas and Mud Cut ft units ft units ft units Drilling Breaks after before ppg ppg ppg Gas during o o o gpn gpn fpr;¡ fp n ppg o % 0.0000 o o X 0 o TFA: Footage for Bit Run ppg CI: 121000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz, Description of fillings: predominately small slivers, some small chunks, some curley as """', :,¡' ',·":~I" "'~'~l\"~" ,.',,"~- % \" .; .\;-~'~·l~cI.: '.. ~~", ': ;","W~'~" ' ., . . after ft ft ft units units units %LCM , '~ " ..' ;~. Sst % Lithology Sltst Sh ppg ppg ppg 24 hr Reci Displace Well with Brine Solution and Oeisel. Nipple down Riser. Decision was made to stay on NS22 and drill intermediate hole do to the lack of ice. Nippled up BOP's Logging Engineer: Mark Lindloff / Doug Wilson ~ '....: " ;>" . " * 10000 units = 100% Gas In Air I I I ( ( 1 1 ( spe""'r'V-SUI, D A I LL IN G 5 E A V It:: E 5 Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 6 11/26/2002 3,725 o N/U BOP's Kidd / Dinger Mudlogger's Morning Report R.O.P. Current o o 40 fUhr units Deg F 24 hr Avg o ft/hr ( o unit~ ( ( o o 60 24 hr Max ftlhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm DH flow o spm Total flow spm A V @ DP o psi AV @ DC Gas" Temp Out o o Mud Wt In Mud Wt Out 9,50 9.50 Visc PV 28 secs 1 cP YI API filt Ibs/100ft2 ml HTHP Gels / Mud Wt at Max Gas Ibs/100ft2 pH 7.7 Sd ppg ppg --- Bit No.: Wt On Bit: o Type: o RPM: o o Bit Size: 0 Hrs. On Bit: 0.0 o X 0 o Jets: 0 X 0 -- Total Revs on Bit: TFA: Footage for Bit Run .~ - ,- , '.., ";r."~<'. ~ J . '.': ,'- .~.":. ~:~~" .~,;,~~.:.: ~':.',' :-'~:t .;,.:~.:,'~-:;~:}'\.: '~:,- ~ ,..f; :.:'>~~':1!,:trié.~' _.~~' ¡~\'''ì' K'1J.':':,~i:::~.~1.~~,ii~.~ti';r..~~·~'..:· NA ppg CI: 121000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ..;{ Depth Drill Rate during Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to : ..c:. '''; ..~.; ~. ,'t ,::.;;. .",".~.: !(:() ~.~ .. ~i.~':"':' ':"'.:::':. "',,i:.;,". . ~ . '.:: Mud Cut: Mud Cut: to o o o gpr.ì gpm fpm fpm % SL TST % SST % %LCM ppg o % " 1~~·~t..":·"':";./·,,,:',J~',~J.~·~~!·~·~rl_~':I.,.'~ _".I.~t"'~.,~""}},,.:~. ;::..~:--.I;,·~, . : Ii ,:,~I>~.t.':'¡.. ';".1."",.)' 4...!.~,)1 before to to to to Connection Gas and Mud eut ft units ppg ft units ppg ft units ppg ft ft ft units units units 0,0000 o Current Lithology: SH >~:~...~~:l~/î7;.y,;·.:~'.:7~~··:'\1:,/.>~iMi!·~~~,~~~l~(";~:.ú¡~,,~"~!i'~:'~':¥"4:.~~. ""~~¡~~'~'~}.,;;":~::':,·"'~'.~~~~1:,·,~!t;:~~:~'1L:~~·;1~~I,¡~t.~~~,~~.~; fir j:; :.I,~~¿f.,~·í'," ~:~ ~~:r:~~.~i~~~' ,¡<"\:~".- + ¿~:i: ;." ":.'IY!: ;. ';,":" . ..', " . ..·;,;~".t~i;·'Ø"~~~~';'f!' ~~!~;;:'~:~ ~ ~1I~f( ':'.:":' ~:., .:~ "': .\' ~~~ }<,' ,~',~~,'~('i1...':~:.~~:,:,~, S'. % .' ; . '. ,,1. .....1 'r " t '. .' ~ ,.:¡; ,,~ ....;- " ' t .,' *:', ?~ ft ft ft ppg ppg ppg Drilling Breaks ( units units units ...~~-4~~~~~: after Gas during after % Lithology Sst 81tst Sh before I, I' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Not in Use oz. Description of fillings: predominately small slivers, some small chunks, some curley Os 24 hr Rec¡ Continue to Nipple up BOP's, Rig up to test, Tested BOP's, Service Top drive. NS22 and drill intermediate hole do to the lack of ice. Nippled up BOP's Logging Engineer: Mark Lindloff I Doug Wilson .~... ; * 10000 units = 100% Gas In Air 'II', " " ~ ., 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson SV4 @ 4006' MD, 3672' TVD 't'·· :',' ", ~.;-::~, '\(~i',,"':' 24 hr Recí Wait on weather for helicopter to sling load 9 5/8" casing. Begin drilling 20' of new hole at 18:30 hrs. Perform FIT to 12.5 ppg equiv. Drill ahead. ~.. ~,~ --: . : .) '. ~ ;~ '"~ ¡' ~ . ".";, ~;:: ,t~~~ ppg CI: 18000 ppm ~\ ppg Short Trip CI: ppm11 Feet of Fill on Bottom: ft :: T~ " r.~¡ .¡~ ,. ,.%L.C....M , ~--"'1~ . ...." , In . ;"...:,I:.I-~ ppg I ppg J \ ppg " .",.,.' ; <.",.,.,,,'.,. .< ;>1 % Lithology I' Sst Sltst Sh " : :¡ ~ i ~ , " '. ~~y , ~'.~~ [~1 ,:,I·r~'-;·~"':~:<·~'~~~".'.'-·'!, ",:.~;"~"" ·-'·:'~'··'I· "-\..' I.··~,'_",:,"·::~'t··' '~:.~- ,to oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: predominately small slivers, some small chunks, some curley as Gas during after before after Drilling Breaks Drill Rate during before to to to to Depth :·¡i"·~\~~~::~Ü~:~,,:~·~·~.~~o?~:~~;~~r~, :.'.ü~ff."'::~'~"}~I~!it"\t ;~.~ ~~.: ':S ~ ~'-.' r,¡;~s.~~~\i.f·.~)iltl~'r~~1~/~~~~~.:.J~~~t ~\l.:f"'~:':·~!'-~:' fJ'~.~.':~ / ,·t~, \~~¡j;~ \~-\. -¡",:.:-. ,~': ~ -.,.t~.~~.~ '" ~ . t:'~~ ~':' ~, :'I~. ',';':"'.' ppg ppg ppg units units units ft ft ft eonnection Gas and Mud Cut ft units ft units ft units ppg ppg ppg 0' ,0 SLT ", . . I: :,!.'~..'.' ¡;~~·I··~~111~...?~.~t~~.: .f·r.'r~·,\' ·l".",..I~.·"~ ~~~~.:..,; ....... '.~. ...... 40 "'", ""'t~;I.'.·, i ,1- % SD 30 , ~ " 01, 'i.""" ' "...\.1:" "', ., ..."' .' '<', ' .f'." Mud Cut: Mud Cut: to ~ ~. . , ,---,J..-' ,..,~,';'t' r. ~~ '. :... ¡; '~: . r 's'" ~:... ,..r. ~ " ....! ~ ....~. .-::-... '¡'''' ~,¡~ '¡~ I. ~ ,.. .., ~ < ~':~ . -" . :..o1'...;...·'~I\~. ':t.."::.~~,: 1::'~::-"'~';''''~':' ~"",'. ",.- ~ .'r .~'':;''¡';. " 1.0060 393 2 X 20 TF A: ---- 15.6 KREV Footage for Bit Run Jets: 2 X 16 -- Total Revs on Bit: Bit Size: 12 1/4" Hrs. On Bit: 1.8 MX-C1DT 100 --- % Mud Wt at Max Gas ~ ppg 8 Ibs/1 00ft2 pH 8,7 Sd 0 units units units ft ft ft % CLV 1~"." '. ,':'1f, ,..*~" ...:....~I~..,.,>'..r .~..~';' ,·',~.~.,';r,...,:--:.,· 40 J'.'J.,,' ..: '. ~~\7 to Trip Gas: Short Trip Gas: Visc 58 secs API filt 11.2 ml HTHP - - PV 15 cP VI 19 Ibs/1 00ft2 Gel~ 6 1 7 gp~ 9 P r.-: fp r:; fpr.1 Pump and Flow Data 104 spm DH flow 102 spm Total flow spm A V @ DP 1550 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 871 165 248 4060 3996 24 hr Max fVhr @ units @ deg F @ 7 11/28/2002 4,118 393 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 977 32 60 24 hr Avg 218 ft/hr ( 22 unit~ ( ( % Current Lithology: ',.,'1 ;I....I~... ....:....:. ..,.¡r.~,... $')'. =",~~ to Trip Depth: Short Trip Depth Tight Spots: ft ft . "",' 2 Type: 20-25 RPM: Bit No,: Wt On Bit: ppg ppg 8.60 8.60 Mud Wt In Mud Wt Out ft/hr units Deg F R.O,P. Gas* Temp Out Current 225 32 40 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: sper'r')/-sun D A I LL IN G 5 E A V I c:: E 5 ., . .~~..;~_...~. " I 1 1 I ( ( I '~~'~...::. .," ...: I,~,.~ ;"','.¡ Logging Engineer: Tom Mansfield 1 Doug Wilson * 1 0000 units = 1 00% Gas In Air SV4 @ 4006' MD, 3672' TVD; SV1 @ 4941' MD, 4483' TVD; UGNU @ 5347' MD, 4839' TVD . "......~ :]'; '; i.,/ ~~~,~~~,~~r,,:f~':' ~.~~..,i:;·~:: I ; w , Drilled ahead. 24 hr Recí ,1,:';; : ,~~.': ".: ~;';~\ ' . ,~',i:'1~:)':~~",'~,~,~ "',' ~ <"'t'~"~ ,~. i!!~,<, .::~ ~,htf·~"~::;':,:~,~:"",~?;~.,:· ~~":j '~''':,; :"1'~~~1:·.~·;1~ IV!';',..\ (;' ,~It':"t'\' ,< ~,,~...,'~ II. . ;!. . : ¡'''' ....~·I· . ~' ~:,~,,~,' - '.": ~ " :"~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 13.3 oz. Description of fillings: predominately small slivers, some small chunks, some curley Qs . -, " ."·",,"'-,:;,::;~:::t:.:\:, ,". % Lithology Sst Sltst Sh Gas during after '>.' ~:~'~:-\:'.' ~,·'¿-.:.j~~(I~~~::,·:li!,:tr/~·~;' r...:~..~-,. ',;~' I~~ i.._ ' >~~;"!'.~:,-' ~.j .\..,. . ~~ :~':~"r r...· ,~'.,,, " , . , I", ','.,-. .'" to to to to before Drill Rate during Depth after before Drilling Breaks Connection Gas and Mud Cut ft units ppg ft units _ ppg ft units ppg ft _ units ppg ft units _ ppg ft units _ ppg r ft _ units ppg ft units _ ppg ft units _ ppg i. _ ,~",,":-~~",h1 ", ,,;, ·r.~..:'t-,~"':\r.~";!F¡"i~~\.¡¡"',Ú~'¡:'''-";',,,;>,,~-;:.~,,,~' ,,~"". .~-::.,:-,!·'¡.!,,,,1".:ll~;:t~N,~k'ii,~'k:-,:t.!I¡J~~!i£"..;I,.,:.' ': ''\~',·il:'.~~~o!'ìI'(~.àt'!!i''~.~..,..'i)'·'' .:",~' r '.;"'1.," :,'''.1 '\,,:~:¡;.,,¡¡:bt ( ~"óLCM % "1,", ",i'~':;'_:;"-'~ :'i~~ , .', 'If.:',' !'gi'~I\1, ,~......è.,-,~_ ;.:;"',~:. '.i~',~''';.,·,n; .,~.'¡.,¡",~.¡;" :Vf~''';'E,*'"..~,tf.':.~h;o t:'""-~¡'I'(:i,¡J,"\- :~~';-':'.~,-; '_."M.:,.q¡.¡.:!ithW-~,'·I~ ,~'w~~;:r,~~l'::,~,,' ~:.-,..' ,·r.. _,' 01 :0 . : ·~".1 ..' .. % % Current Lithology: 1 ... ~';oI'~ to" ,II;', ....,.,:'_~ .~'''''. "!, ~~r": ",.....~.'.(::;~~. r .i., ... :'.. . ,i., ...... !I ':lIw)" :.:.' "II...·'.t.~I' .~!-'..~. ~~~.;¡W'~'tt;',,~. .':':I~,.a;-r~' ~ "''',i ,'," ~'. ,/~·r/'..;J· ;":J.,:. 1_ ,'. :' I ~:)':.':,,'~~.'"'~ ~,:.~p'~':"~~I~..'ið..r'''I-'h':!I'..'' ". \ 'I. ppg CI: 18200 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft " , Mud Cut: Mud Cut: to Trip Depth: Short Trip Depth Tight Spots: ( ft Trip Gas: ft Short Trip Gas: to to . >'f' '.' - .. " ,,;....... ~ . .~... ~~:: 1· ".~.~...~ :",,' ~-,\."".' ..,. .. \ Jo'., ~!.~:~~ ,>~ :-~~:"'.~ d,:,' ~;~·;Y:.W~·,7",.j: _...~..~ ~:;f¡-;:. ,,~~:-::{,~,Jo<':' I ¡.'}'.',¿ .,.... ~~;I :::'.::" ":,~~ ~: ~:.~:..:<~~;~':~~'!". ~ I 1.0060 2,929 TFA: Footage for Bit Run Jets: 2 X 16 2 X 20 ---- Total Revs on Bit: 94.3 KREV Bit No,: Wt On Bit: :. ~··'t,·i;!·· Bit Size: 12 1/4" Hrs. On Bit: 16.4 MX·C1DT 105 Type: RPM: 2 30 6,0 ml Gel~ ppg ppg I HTHP _ Mud Wt at Max Gas ~ppg 8 1 10 1 13 Ibs/100ft2 pH 8.9 Sd 0.25 % --- Mud Wt In Mud Wt Out Visc 47 sees API filt PV 13 eP YI 23 Ibs/100ft2 8,95 8.95 gpí:l gpr;¡ fpr;¡ fp r.1 Pump and Flow Data 101 spm DH flow 100 spm Total flow spm A V @ DP 2100 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 850 90 242 8 11/29/2002 6,654 2,536 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 4598 6160 6458 24 hr Max 1164 ft/hr @ 591 units @ 95 deg F @ 1 24 hr Avg 175 ft/hr ( 30 unit~ ( ( ft/hr units Deg F Current R,O.P. 50 Gas* 18 Temp Out 95 BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: sper'r'y-sun o A I LL IN G 5 E A V I c:: E 5 * 10000 units = 100% Gas In Air ,'-"," ," % Lithology Sst Sltst Sh Logging Engineer: Tom Mansfield 1 Doug Wilson Schrader Bluff @ 7148' MD, 6432' TVD d~'L~I'¡~), ~:,:,~ ¿4'~:;J"::¥::./.':'~, . Drilled ahead from 6654' to 7738'. Circ. High vis/fibre sweep. POOH to shoe. -,.., ~ :~·'·:,*·::;")~~,I /: ,,:~..;~.~;,~,;i ;~ :', ~.:;"~~>'.' ,~,:.,,~.,~·~~i:~~i\\~,:?;¡,' ~1-i~~-'l.' " ,,"~..'~''':'~'~~.''~'¡' ~_,; . ,:' ~". ~(·,v -:";:,:~ .,..'~" .: ',: 24 hr Reci 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5.0 oz. Description of fillings: predominately small slivers, some small chunks, some curley Os '.: ~.~~:;~~;.: :;', \. 'I after Gas during ;. I·:'~ .~. ":: :r-:·.~.t::'~~:'~:'·~'I\':~Y~:~~~~Y~::.·~~'~;~~· ......... " '~ <~t.~':. ~..~~:',:~..: - .... "" ~., \' :.' .~;'~ I before after Drill Rate during before to to to to r ~ Drilling Breaks Depth units units units 1 , ~ "~'¡" y:ry ".,"; '1:·Y:r~".f!.·,1j)'i:"¡:','·~U¡.;r~,~~~·,~;;l::;i,~·,'n "iH",'IJ :,.}:"·ii1f1,~*~,~"wjllW.. ~f·,j,'¡.·nW~f,:.~'!,;,~':'t'<,i.:tt;"·i;i!\;,!,~f.I,!" "I'!\"",~~ "I::,·.:i}~.,~~~:,;¡;~,::~··::--·" " :. ".' ",; I:~~~,;""'; ,"fi:'-',' '.'II~ ppg ppg ppg units units units ft ft ft eonnection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg ppg ppg ppg ft ft ft %LCM ·~",,"'1~~:f:i~~~~~~~~"~','J~·~~~~it~~:~~_~:·I,<'~'·!'..:"'·:~':9'<;;'7""L:::';.."i!."..:;;,.,~,.".':i..~n«,"! ( ,¡ì~( .' "" .. ,..:,;.. .~.~¡~:..~!;,<,(._;,;; '."·<;."¡'.iiI¡¿"'\";J ':"'~;t~~"~<,:~.\~,,,~:~,::,¡,:~i':\oi~'(;<Ò;::.~;:,~,<'\:,·!.~'!$._,;#0\"\!,)p.~&;¡;::'Ì'·;~(.i~"~f,~~~"~1 )c,?W,.... ' ,.;;, "';':!i!'!(.<'';'''''' '';;:',è~,,' .~~'''''·~~¡'k""1.~~r,ol.,~,~"",!,~.¡t \", . i ':' .~t Current Lithology: % % % % ~~~!'~ 3Z"!-:·'1'~'';·~:'!'.~:",.~' i~>t ,';", "".:. ppm ppm ft ppg CI: 18200 ppg Short Trip CI: Feet of Fill on Bottom: " "":... . \ .. ........... '~'. --t.... 1,0060 4,013 TFA: Footage for Bit Run 2 X 20 -- 165 KREV Jets: 2 X 16 -- Total Revs on Bit: Bit Size: 12 1/4" Hrs. On Bit: 29.7 MX-C1 DT 90 Mud Cut: Mud Cut: to na . ~'~~t.', I~ ~.~r~\·::.~·' ", l.~'i:·'~' I ~"',~i,, " ,', ~;.:·Jt~::.r·":~:. ',_; .~ -' -..: . ii -',' .," .",...~'.~"'\.'~' ~ :~,.",,¡~..""';~ ,.~,\. ~,,::": ~,';.:\'.<' to Trip Gas: Short Trip Gas: to 7738 ft ft Type: RPM: --- HTHP _ Mud Wt at Max Gas ~ppg 8 1 10 1 13 Ibs/100ft2 pH 8,9 Sd 0.25 % gpr:¡ gpï:l fpï.1 fpm 1030 111 299 Pump and Flow Data 122 spm DH flow 121 spm Total flow spm AV @ DP 3450 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 9 11/30/2002 7,738 1,084 Bit Trip Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 hows: 6.0 ml Gel!: Visc 47 secs API filt PV 13 cP YI 23 Ibs/100ft2 ppg ppg Trip Depth: Short Trip Depth Tight Spots: ( .1,' . ."/ ( 2 38 8.95 8,95 Mud Wt In Mud Wt Out 7248 7614 7738 24 hr Max ftlhr @ units @ deg F @ BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 395 195 100 24 hr Avg 136 ftlhr ( 50 unit~ ( ( ftlhr units Deg F Current R.O.P. 209 Gas" 30 Temp Out 100 ( Mudlogger's Morning Report f Customer: Well: Area: Lease: Rig: Job No.: sper'r'v-sul' DRILLING SEAVIC:ES . ~ ,.' * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Recê POOH to casing shoe. Wait on helicopters to sling casing to island. Continue POOH. Test BOPs. M/U new bit and BHA. RIH to shoe. Work on pump manifold. Schrader Bluff @ 7148' MD, 6432' TVD .' "'".; ,(:..?;-' ';""/ :::~:~ ~~~,,1 , 0.:.':'. C ,,;.... " ...... , ;, ~ ': .<:. . ./ ',. " :~"\ ~ \0'" '\ ~\. ,"-"': ~~, ~ <; . '::~" :·~~,~~t;~\'-(. ::( "~~:;>"',~, ': ".~;': ,ì::~: ..,,~~. .. :" "., 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5.0 oz. Description of fillings: predominately small slivers, some small chunks, some curley Os :' ., '. , ,. , ':4'. ." :,~' to to to to ~}r, Trip Depth: 7738 ft Trip Gas: na Mud Cut: ppg CI: 18200 ppmtl; Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ¡ Tight Spots: to to to Feet of Fill on Bottom: ft '~¡ Current Lithology: % (I/o % % %LCM ~ ,.: .. , ..: ;.', '~·"l-" .' '''''';''~':-''M' ~ II.'.';;,"";':''':'; :'. ,"" '._,. c :'" ''', '., ./' . ',., "', ',~' ';-:':~"to.if;;,;..'."~!;:iFt,~.I" :,: , ,." ';,,: ,,,~..'..,.. ' "'~'I.. '.<','1, . .:' .-'; ; ,~,..."',' '., ~"".,."' "...;)""",j,.i,,,.,,,.,, " " '.. " .' .. ":.' " ~."t,~ I Connection Gas and Mud Cut . I ft units ppg ft units ppg ft units ppg I " ft - units ppg ft - units ppg ft - units - ppg '3i"'1~ - - - I . ft _ units ppg ft _ units ppg ft _ units _ ppg :,,- ¡¡·~::t:·_~~¡"·ii«'" .-~' .,.., -" ""<~·'·":~II:~'-~::;I:;:~¡':::·'~" " .':::"'.:..-- --'~ ,,,-,,~.:,.,. . o/:iLI::OI~Y";" .\,.. i before during after before during after Sst Sltst Sh W; I'/" '1[; 1 I I 1 I . ."'~', ~ ':"~,'',,I .,., '. ,~,: ~ .: ~ '":: ... ~t" .. . .- 1,0350 o X TFA: ---- o Footage for Bit Run Jets: 6 X 15 -- Total Revs on Bit: DS69HFGLNPL Bit Size: 12 1/4" Hrs. On Bit: 0.0 Type: RPM: 3 ppg 0,25 % HTHP Mud Wt at Max Gas 8 1 11 1 13 Ibs/100ft2 pH 8,5 Sd --- Visc 52 sees API filt 5.0 ml - - PV 13 cP YI 21 Ibs/1 00ft2 Gel~ ppg ppg 9,10 9.10 Mud Wt In Mud Wt Out i¡:m f¡:m Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV@ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max fUhr @ units @ deg F @ 24 hr Avg fUhr ( unit~ ( ( fUhr units Deg F R.O,P. Gas· Temp Out ( g¡:m g¡:m Current 10 12/1/2002 7,738 o Bit Trip Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report f spe....,r'V- sun DRILLING SERVices I : ,...-... . ~ -:" . ~ ., 10000 units = 100% Gas In Air ." ...::~'\~: ~. (::~ '. 1 .\,I"~t :",,:<. 24 hr Rec: Complete RIH. Trip Gas of 102 units. Drill ahead. Packed off @ 8527' wi PWD of 13 ppg. Got lost fluid back with pumps off and 295 units gas from bottoms up. Continue drilling ahead. Colville @ 7799' MD, 7004' TVD . '~~:" :~ J.'\' ".":' ~, ;. .: .~; " ~..';' ".'. ~~:;~~ ~'~ "'~. I' ~:I,,;l:I,~~-.! ~\~'"" !',~' .t:" ': .', :j,". Logging Engineer: Tom Mansfield 1 Doug Wilson .:'. ............ ~- . ',~'.:)~~,.~,::~ï;·}< . ~'.!",~ '''/'':~:'': ~:.,. I "\r~ ',::; ,/ ,.:, ':.. ,;.~ ,::::·'-·;"¡·~r-~:'~.,~,·~~::,~'¡~i5·;~~~;/~~~~b~::;~.:.:,:~,~~~~.~~,~ ;~~ ;.~1.:"';"'" 24 hour accumulation of Steel Filings from Possum Belly Magnets: 17.4 oz. Description of fillings: mostly small slivers, some small chunks, some curley as, Most from shallow pulse test. % Lithology Sst Sltst Sh Gas during after before after to to to to Drill Rate during before Depth Drilling Breaks Connection Gas and Mud eut ft units ppg ft _ units ppg ft units ppg~' ( ft units ppg ft units ppg ft units ppg ~ ft _ units _ ppg ft = units _ ppg ft = units ppg ~ ,:..·~\¡4, ,;:~';">Ø~,;¡¡:::;.o ~',*''Fj.i..: :i\"{-M'~'¡ ...#(:.'Ii.'....~,~,': t:~·,~~..¡ ..', ... <':t~~'p,r,:.-~·:;~.¡·,~.i~~~j··,/.')~;.~~~''''~',~ ,;;:'i;:.~;..~~,:,.";.,.;;~,,~i:"~,-,~l~'W~::~'.';""·~·'·":'·,¡f.':·' h·f:'1<::<,,·" ~·J>.Þ~·:~~,/;¡- ,,;'~':-.4J'1!. '.~,I,,;;,~· .,.t...f-~\._I':.Ift.. %LCM ~'o (.,. '. ."Y,~.~ ~ :,.'" ".< -r.:~J:'..~ 1- !,r~', .~: ....... -,.~ I' ~ ~ ...... ¡:/ ~'·~.t~·,~ t~~~N~'~·"'!~;,&:""~~·.'''··· ;, ;, . :~. J~\ :~,; r· "'. t~' , . ~¡·"';.·rtl ;1..·I~·r ~ft·~)r.':-iI!t4.'(".:. .', I' j .. . % 0' /0 Current Lithology: ......"", ; 'r 'Ni~~1 :~. HI~. .... \, ,', % . ...~.,' ...:.~ _.:......:,~:"J-.;.: '. :~?~...~,"..(.rr.l~.~...,-::,.· c::..i ,,,. I ï 'h " ppm ppm ft ppg CI: 18000 ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to 102 ,,' to Trip Depth: Short Trip Depth Tight Spots: to Trip Gas: Short Trip Gas: 7738 ft ft ~.'~~."-.~ ~"'~~.",. ·{I~I.~;:. . ;,'f:.¡'~:?::.; ~.' .", ..y':. "J. ., .. ....) ':",,'~~:'~;: ",..~:,;.',.,~"",,,".,,,,,,,;,,...,:,, .;....., , 1.0350 1,407 X TFA: ---- 116KRevs Footage for Bit Run Jets: 6 X 15 -- Total Revs on Bit: DS69HFGLNPL Bit Size: 12 1/4" 1 00 Hrs, On Bit: 10.9 3 Type: 15-20 RPM: --- HTHP _ tv1ud Wt at Max Gas ~ ppg 8 1 10 1 12 Ibsi100ft2 pH 8,0 Sd 0,25 % 7.6 ml Gel~ Visc 51 secs API filt PV 15 cP YI 22 Ibs/100ft2 gpm gpm fpm fpm Pump and Flow Data 96 spm DH flow 96 spm Total flow spm AV @ DP 3100 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 990 105 282 11 12/2/2002 9,145 1,407 Drilling Kidd I Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 8086 8518 9000 24 hr Max ft/hr @ units @ deg F @ BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 ppg ppg 9,20 9.20 Mud Wt In Mud Wt Out 304 295 105 24 hr Avg 129 ft/hr ( 55 unit~ ( ( Current R.O,P, 171 Gas" 50 Temp Out 105 ft/hr units Deg F Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sper'r-'v-sun DRI LLI N G SERVI c: E 5 '"' 1 1 ,.'"I"!~,';',,....¡,...:'.: I',' ¡':,~;'. . . . I J," ". ( I I I 1 I . .',.., . ., ;' '~ :.... .,' "" . :/.': " ' " 10000 units = 100% Gas I n Air Logging Engineer: Tom Mansfield / Doug Wilson Top HRZ @ 9839' MD, 8795' TVD; Base HRZ @ 9930' MD, 8871' TVD; Kuparuk @ 10040' MD, 8961' TVD Drilling from 9145' to 10246'. Added spike fluid to bring mud weight from 9.2 ppg to 10.1 ppg. 24 hr Rec, , . , '\1":1,- ',; , . ': ~...~~ ::' L',:';\( ", ~:,.,:~~;,~,~~~~;,>~·,,,-,,~·'!:';~·t~F:' '," ',::'}~' ':t ~ ~,I';~"''' . ~ . . .... ~. ;. oj. .<~. oz, 2.9 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: mostly small slivers, some small chunks, some curley Os. ,,t ,.....¡ . ,. ,.' <';';"'~""':":" t . .." " . , to to La to .,' " '''', ~. Current Lithology: 40 % Shale ~ % Sltst % % %LCM _ l ji ' ".) .,;-,,:.:.,,:, ,;~,":,;<,~:":,'t1j'~''i.;:$t·m.~;',,,:;;..;,,..!>:,":,;!,¡I¡..'o\'o\!¡'-:'<'''::,...",'~ ,Þ,;,;:.:""·il-"·-:'~'~~· ~ :;~.':'..-, ,,·:;:,'w.....,..·, ';,."' ";' :' ··";'~""",~1,'" ..··'~l"J¡~!!'..':"'!"'\·,,,'.. ':':.' "'" ',' ' ","" ,,~{~ I~¡ Connection Gas and Mud Cut ':'~¡.. ft_units ppg ft_units _ppg ft units _ppg : ft _ units ppg ft units _ ppg ft units _ ppg .~~ ft units ppg ft units ppg ft units ppg w, ~:L>;i~.¡;;~;~":...~>':~~~,::~"~~it;.G~!~~;..~l~~·~~~~1f*~,.~:"~~.or,.0gi :c:-"."c'.."~>··.:.::,,~.¡¡,r;~¡kl¡\'tMH..,;~~r¡¡;~~~~~~i·"'I¡¡,~:t "~'~\¡}> ¿~~,;. ; ',:" ...¡,,,~.~"'_~.....~,~<¡f.:r~~ ,j;~'ffl\'. '., ,(" ~ "~~ t'; ~.. ~, i wi, ;';,.r~:'¡ ~ r I . . Drilling BreakS· 1. ;11 Depth Drill ~ate G~s % Lithology " ,. before dUring after before dUring after Sst Sltst Sh .t i~ ( 1 , ·âj~ .' ~ ..~~ ~ " ,,', :~~:..\~, ',i... "1. '-', ( ',"; ',:~: '~.~';. '..' ,,~ ,71. "' ~',r:l't ~~",.ti'"....~'. I~ .>. " ' ,~ ;. ....,. ",:r ~ ., ' . ',r..~ '..;" . :~;.¡ '':Þ~;'~~'' ': p ~~"" ~'.~'o'," : 1I'."Hií~~? ~ J! <1:C~ It ;. .,.,.. . ,. ppm ppm ft ppg CI: 18000 ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to to to Trip Depth: Short Trip Depth Tight Spots: I Trip Gas: Short Trip Gas: ft ft 1.0350 2.508 X TFA: ---- 247 KRevs Footage for Bit Run Jets: 6 X 15 -- Total Revs on BIt: DS69HFGLNPL Bit Size: 12 1/4" 1 03 Hrs. On BIt: 26,4 3 Type: 15-20 RPM: 1 45 secs API filt 15 cP YI 27 Ibs/100ft2 Visc PV 10,10 ppg 10,10 ppg Mud Wt In Mud Wt Out ( 4.2 ml HTHP ~ Mud Wtat Max Gas ~ppg Gel!: 12 1 18 1 23 Ibs/100ft2 pH 8.5 Sd 0,25 % --- 1 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. 184 fUhr 71 ft/hr ( 262 ft/hr @ 9860 ) Pump 1 109 spm DH flow gpm - Gas* 150 units 95 unit~ ( 467 units @ 9851 ) Pump 2 109 spm Total flow 922 gpm Temp Out 110 Deg F ( 110 deg F @ 10129 ) Pump 3 spmAV@DP 98 fpm Pump Pres 3200 ps i A V @ DC 263 fpm 12 12/3/2002 10,246 1,101 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I sper''''''Y-5un D A I LL IN G 5 E A V I c:: E 5 I ~. ,~ * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson Tops: Kuparuk C @ 10328' MD, 9193' TVD, Miluveach @ 10670' MD, 9467' TVD 24 hr Rec: Drilled from 10246 to 10743. Circulate hole clean. POOH to run 9 5/8" casing. Began pulling tight at about 7930'. Pump out until about 6500'. Continue POOH. ,', ""', :"'''',( :,:¡.: ' % Lithology Sst Sltst Sh 80 20 ... ,;, '.'·r : ' \ ,.,:~., ~:¡,;'t':': : ..~: '.:¡.¥:;~.:~J.~:~,: ':·:...t~ ')~ ~ '~..,~:, . ,'. ',,'; I. ":.~ ~{'~ :.',~. : '~~:~.~~ '..'~1 .- .. ''-'j'!.'' '1 ,}~ ';~:-'.. ~/~-,'-.~, ~ ~'£(' ( ~ ~:..'.:~ : './;'/~·~'·t'., '" :..< oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: mostly small slivers, some small chunks, some curley as. 2.9 after 220 Gas during 703 after 95 before 100 1 0328 to to to to I 10480 before 150 Drill Rate during 230 Depth Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg ppg ppg ppg 1 , .::~,",~t~J.·'~.~,,~;·'·'~"~X,\'IÞW~t~~!¥.i§Iii~~~r:~~'~~'''. ,:"..;.;.;t,:,,;i";~:~'¡('jj~J>; ~~;¡':'I'0Dl:::A,:';'~ ~4"¿b{Jt~j;:tW3'::;"~:':\"t~,.:·. .~»." "~ :r',.;. " ;.. :, '.. ¡,,~"L~'Î\*'~..s~'~¡:I!é}· "~'~'>'':'Ú ' .",..,.' "\' r.',., , ',~,': '\';"'1~: t,i . '~~~~"1"¡ ppg ", units units units ..... ..; ., ~'oLCM units units units ft ft ft I '.I;~: ~.tt,.~~ .~"I~.J.:t··I'!1.,..~·/,,: I'. ::"~~: ~:'~)." . ..' ~,h, '" '. ~... I ~ . "',"'~ i..' ¡. f~1 ~" :1, .,....:.! ';~,. .:. ::.....:or.~!;"i~If'~~~1.~ ...~~,. .... '.',,'. .... ~".¡ ~,~ .', ,f ;.. ':f ~'~" :':~'~~"':~ "~ ~7}'I ¡", ~~ ..... I ,".-~" ~I ,', . -~i. . i'·~.¡:~ ". ~ . f' I',:. I' ¡.;. I '0: ! "."~ % 75 % Sltst 20 % Shale Current Lithology: 1 % Sst 5 .,-',' . ~ '~~~-'¡IIo"'-1't~·ir. r . . '.!",'L.'"+,!· IW " ,. .~...I,".~"f' .·I'.~.t"':-~:·'~~·~'~.$.·:":'~l";~"\.,,,,,:, ~ '.' .', ... ·~"..,r.· ·~·I~",~·~;·I·~~-·"'f"ll'j~~.,~··~·w!Il.I...·'·'I"I" ··'····'f Mud Cut: Mud Cut: to to to Trip Depth: Short Trip Depth Tight Spots: 1 ppm ppm ft ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: 10743 ft ft , '~i ~.~~....'...~."."....... Ì¥ :~ m, 18000 , , , . Trip Gas: Short Trip Gas: .,' . ~': :'i ~. . ..,:~~\,~.~ :I,! .~~ !~'J~. ' . : :< I 1.0350 3,005 X TF A: ---- 326 KRevs Footage for Bit Run Jets: 6 X 15 -- Total Revs on Bit: DS69HFGLNPL Bit Size: 12 1/4" 1 03 Hrs. On Bit: 34.6 Bit No,: Wt On Bit: 3 Type: 15-20 RPM: 10,20 ppg 10,20 ppg ( Visc ~secs APlfilt ~ml HTHP ~ Mud Wt at Max Gas ~ppg PV 13 cP YI 25 Ibs/1 00ft2 Gels~ 1 ~ 1 ~ Ibs/1 00ft2 pH 9.0 Sd 0.25 % Mud Wt In Mud Wt Out I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 90 ft/hr 60.6 ft/hr ( 230 ft/hr @ 10416 ) Pump 1 spm DH flow gpm - Gas* 125 units 170 unit~ ( 703 units @ 10420 ) Pump 2 spm Total flow gpm - Temp Out 111 Deg F ( 111 deg F @ 10743 ) Pump 3 spm AV @ DP fpm - Pump Pres psi AV @ DC fpm 13 12/4/2002 10,743 497 Trip for 9 5/8" Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ( Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: DRILLING SERVICES 5per'r'V-5un '.~ t·· .~ '...~ . - .~..' . ,~' , * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield / Doug Wilson oz, , ::~.\ ;"'i';-.: Finish POOH. Repair top drive. Change out rams. Start running 9 5/8" casing @ 17:30 hrs. .' .~'( !I.~ ."":',1 :,' . ~J;"¡:,~::.. .~~r";.'t'. '~'y.~·f':'~~·g:·~f'.I', ..~:1f:'~~ r~-':" ..\J~...';:~: ',,' ,:",~. ;. ~\,.:... '::"~! ~>' :·~:/:;.~.'!,(.;~~:·il..~f ,:,:,~;~:,:{¡,~~I .', (. '. 1õ~.~,~; :.~. ..... . . ,'. 'l"'· '.J, '1' .~,<: ~_, ," 1<0' ,.' .,.!.. ~.', 'i I ,( I % Lithology Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: !~ ".. '\'··,..·~,.·F:nX+;'~ï~~ï·,~~~~.,~¡-<;,~,.>-';;~!¡,:;.¡¡;."',(:",':'.\ ;:;·þ.';<~:;I:~1'<:t~:'iJ~i¡,~,¡·¡¡:,~.:.',.j:.!';,"6-··~.lt·;~~!I~.*;IÀ,~i.-,;,·¡;';;.:·,~· .'~'l'.i·;'~.~<·' ,.' ''', ......' ,::"j".. "'. : ".!,.';J';'¡r,'I;-:.:h'",:-><:";t. ';:.~ ppg ppg ppg units units units , ~ . .,a ~:,"'?(~... ~'\:'" '.. ~'. ", ~ ' %LCM to to to to after Gas during Depth Drill Rate during after before before Drilling Breaks ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft units _ ppg ft units ppg ft ft ft ppg ppg ppg units units units . ,., ':.... \,r "'w ~·.li;I'-' ~~'; '_i.':" ~ ~,.~!;',. R,. ",'~;'I' ~";I' ~ ''''~. t. ',I__~ .....';. ,- -.::.... -,' ,:/.,~,'It ';"::"!'::-P'~t.t" :~:fjli;. ~;~~..I,'~'.' '1"). :':"l,r.~! ".:;. "~~":'''¡:,,. ~~,: .~~~~ ··':.~'.~r;:';~:" ...,' '·.i..r·~'¡'¡~7·"'-\:~~." % 20 % Shale Current Lithology: Sst % 5 75 % Sltst . l¡11~~'~r6 """f~.-I:'" ".,1~~1 .' ¡"';/ '. ",:'~"'~" ;r~" ~,.'-}.- .', ~, ..~' ,"1. ',' ~ .~,1~..¡, :' 'I"'.'t~,~,".~:;~)"-;'.~. .....:.. .......,. . ,,'" ".~ ,~I '.' .,'_ ppg CI: 18000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft . .. . ~ ". .. r" ':.:....."."". . ~'h -_,.' ~ .:~::':,': ~" . " ." : Trip Depth: 10743 ft Trip Gas: Mud Cut: Short Trip Depth ft Short Trip Gas: Mud Cut: Tight Spots: to to to 1.0350 3.005 ppg 0,25 % gprr. gprr. fpm fpm X TFA: ---- 326 KRevs Footage for Bit Run Jets: 6 X 15 -- Total Revs on Bit: DS69HFGLNPL Bit Size: 12 1/4" 1 03 _ Hrs, On Bit: 34,6 3 Type: 15-20 RPM: --- HTHP 11,2 Mud Wt at Max Gas 7 1 12 1 15 Ibs/100ft2 pH 8,0 Sd 5.2 ml Gels 10,20 ppg 10,20 ppg Visc 44 secs API filt PV 11 cP YI 23 Ibs/100ft2 Mud Wt In Mud Wt Out Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC 14 12/5/2002 10,743 o Run 9 5/8" CSG Kidd I Dinger Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ Current 24 hr Avg ftlhr ( unit~ ( ( ftlhr units Deg F R.O.P. Gas* Temp Out Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: spe....,....,v- sun DR I LL IN G 5 E A V I c: E 5 '- " 1 I I ~ i I . - ~ t ..! . ,'1 ~ ... <""", ~ '. I ·f.. i~ .. ':~: , . :. ~ ',' '..J. ~ . ~ I ,.. 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Reg Wilson ,~~., ,10, . .... ,.?.~., , " ".~' ;.'''\ '~,.' .",-, '1" ;...:..'. :-:".',:;'r~I': Þ'.'t,:J .. ';.'''.,,:.~ ',":':"'. ,." ~j".... ~.'~¡J!~iII~.:";", '~..'! i'"";,",";' '¡-". ':,~'¡;';': '.,' ".' ;~' ":' .,,':, \""\!;)"~'~",\',~I!J~!V<1 ,., ,,: "1": '; "', '." _...~ It Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units - ppg ft units - ppg I . ft units ppg ft - units = ppg ft = units = ppg ~, '?~..,~. :i;i·.·i,·~~·¡ /'¥.~~~i.¡¡1i<'5JI:~~~b~:<·0.'~\1I¡!;ß/~~::il!;:,·. :':·~'",>tt:..~k:;d.:·:,;t,'\'I'M;¡"·'~_"f~i"tt'~,:f~~~~";¡~~·;::¡f1..':; ¡.r~·~~,' :',.4"< .q¡''';'~.;¡:~~~';~j;~;,'', " " .' ;,/ ~/fli~"~.N,:,"., ,..: I . ...... I . .', . . Drilling Breaks ì ;~I Depth Drill Rate I before during after before ppm ppm ft g¡:.'":1 gp~ fp r-: f¡:n 24 hr Rec; Finish running 9 5/8" casing. Landed at 10680' MD, 9475' TVD. Circulate casing volume and cement casing with max gas of 1816 units. Clear annulus with 230 bbles of mud at 112 bbls/min. .... I'~ ,I ~. ;::. . . \~,-._ " " .~.~ 1", , ~ ~ ,¡', . "":"~ "'r}' ,'... .\,. :·~";'~;·;~:l ....:;:~~~ ·....ì·· "(:,,:,,1i'~."'J.. <; .~~~--;,'~": <.·1,": ..' oz, 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: to to to to % Lithology Sltst Sh Gas during Sst after %LCM % Current Lithology: % % % .'<'. ;:.~~,...:r . ~,~,:,}"~;!~ ~ . .J:'.~. :':0',.~';,~, ..;.<,:~- :~;~¡, ";.',.,,~'~:!' .::~:.',~.;;:r .'"'~~;--',,:"~~¥~:';_~;'\':~i?;':.';I'i:,"';:'· ,.0~~/,':~';'-\i:;::::h}~'t":':~:ri:=.~~~~~J~:;"~,,,,::%},..~r-;'·~·~f/!\.,,:,::,l:~t~;:,::<\:',;,·,··..·:: ¡~~ ,;,,::.! ,":.",.¡,':~~ ':T'Ir-~b~~~~~.~,!~ '.~,;..~< :,. ~~.~..~,:I<: .' 18000 ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Depth: Short Trip Depth Tight Spots: Mud Cut: Mud Cut: to to to Trip Gas: Short Trip Gas: ft ft 1816 10743 . . " .:' '~~I ""'1,,,' \t/".t.· ··')··'I·..··'·ÿ .... I' '~.""~",:: ·\':",·,$·,'~····\l~ ~..:,'.,::':;."~.~. , . ..,.. ,.:;: . .'~ ,": . ~ ,'.. ... . Jets: X X TFA: ------ Total Revs on Bit: Footage for Bit Run Bit Size: Hrs. On Bit: Type: RPM: Bit No,: Wt On Bit: --- ppg 0,25 % HTHP 11.4 Mud Wt at Max Gas 7 / 11 1 17 Ibs/100ft2 pH 8.0 Sd Mud Wt In Mud Wt Out 10,10 ppg 10,10 ppg 5,2 ml Gel~ Visc 41 secs API flit PV 12 cP YI 21 Ibs/100ft2 Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ftJhr @ units @ deg F @ ftlhr units Deg F 24 hr Avg fUhr ( u n it~ ( ( R.O.P. Gas* Temp Out Current 15 12/6/2002 10,743 o Clear Ann, WI mud Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper'r'v-sul' Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: o A I LL IN G 5 E A V I c:: E 5 , . ." I I I '1\ 1'): .......'. .~'.., ., .,~ ~i ~~ ~. ;; ,'" ¡' ( I I I "';:' .~. ~: ... J', . ( ¡ * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Reg Wilson ::' '" 'I~:' . ~ t~ :,,". '. ,,', "j .:. f., ' ~. . ,'t 24 hr Rec; Finish clearing annulus wI 228 bbls of mud. Test BOPs. Change kelly hose, New hose 5' short. Prepare to re-install original hose. , ,." .., ~, ~ , >, % Lithology Sst Sltst Sh I.'· oz, after .:....-¡..;:. .. L.: ...."'jl'...' ,:': ' after " i.' ~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Connection Gas and Mud Cut ft _ units _ ppg ft _ units _ ppg ft units ppg ~o !: .,....; ',"..1. :; . I ',.,.,.. I.J ·..;}r·~~.,~"::' ~~ ,1; n.~; ~''9'. :...: 'I. ',~ \ ~":¡\l4!._1~."~1' ','.~. ...~'t ·..1..~'}~r-,·, 01 /0 . '''''-''''.' Gas during before Drilling Breaks Drill Rate during before to to to to Depth ", ~';r:;l}¡.:;,',<II>,'·>i,¡~.>;·n;·~~0Jj,:1t)·(,\i.~"';'lI', ~/..·~1':¢;.;~'·'.)·'l~t"'-:;.·;:,:.~, . ;.: ':. ·~*-~\·Ù~"., "".,,;.' ~#~~dì\.~,¡,·¿··~~ð,~~'(ØÒ;~;~·~ii)r;~&';:¡;;; i.:'-'·' '.~'\~:;'-':¡~';:.i~' i;';¡,.4:~'\~'!,;.,· '~.\";'¡" '~''''~"~ .,:;' , '/":;.4.]' ppg ppg ppg units units units "...~ \~. ~;I.,1}j . '....~., ...1 \ " '," .~ ',1 %LCM ft ft ft ,t· , :. ';'þ'it"'" ppg CI: 18000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft , ,./~ """'. . Mud Cut: Mud Cut: to ..i.,YO ~ ,..' ",' ..:.,,": ,~, '.:. ' : ;tl. "\.', ~. ::~.'{ .~ ";' ? 8 1/2" Jets: 4 X 12 2 X 14 TFA: 0.7720 ------ Total Revs on Bit: Footage for Bit Run --- ppg 0,25 % HTHP 11.4 Mud Wt at Max Gas 7 1 11 1 16 Ibs/100ft2 pH 8,0 Sd 5,2 ml Gels 41 secs API filt 12 cP YI 21 Ibs/100ft2 Visc PV gpm gpm. fpm fpm Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC 16 12/7/2002 10,743 o Replace kelly hose Polya I Dinger Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 ppg ppg ppg , '. I. .,"\ "'."'. ~.,fÞ' ~'" , ,.:. r,', units units units ft ft ft 0' ,0 r¡jl:. . ,....,. ,¡,~'.J...,,:.T,I.."'''''''~'~~.~\''.''I...., ('Ii">(~"'r":'~ '.}" .', Current Lithology: % ft Trip Gas: ft Short Trip Gas: to to ." I ....., ," Trip Depth: Short Trip Depth Tight Spots: Bit No.: 4 Type: DS70FNPV Bit Size: Wt On Bit: RPM: Hrs, On Bit: \" ,;.,::....-.. . :', .. . :~.""" ;'". . . ~".':.' .:' : ''': .: ;.~ 10.10 ppg 10,10 ppg Mud Wt In Mud Wt Out 24 hr Avg ftJhr ( unit~ ( ( ftJhr units Deg F RO,P. Gas* Temp Out Current Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spef'""'r'y-sun DRILLING SERVICES .~". 1 I I 'I'·~. ., " '.'. '. I. !,..','., t" ~: I ( I 1 I I I * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Reg Wilson 24 hr Rec¡ Finish re-installing kelly hose. Pressure test, kelly hose O.K. P/U new bit #4 and BHA. Run in hole to float collar. Pressure test casing. Bleed in spike fluid for 12.8 MW. Reaming to 10743', tight near bottom. . .', ~". . '. , ; ,. ...... . .; ~ " , :,:' , ....-':,......1·..." ·\..···:.\f';.>,',_L.,,; "':"'f.!· ..j,":' ..'.. , . . ': ,'., .:.~: " .~....,......., ~ ~~ ' Jo 1 . . ~,~. .. ' oz, 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ;,1:: ','_1'0,' % Lithology Sst Sltst Sh Gas during before after Drilling Breaks after Drill Rate during to to to to before Depth :,~" i ~ '",;'4"'-"i>:-;f..'#!WH:¡,~;;¡:;:.,~;Iti~i-f)",~""~,,..¡:~tij¡t....:,\,',\~:'~¡~,~"':,., .' '''~~'.~\I.:')-~~,'.''¡'i.t'ffi<''r¥,:::;I,,:~'~;:;<;t!M1;..:i~~iîri:~·':::\r:¡,'o\·',,'¡;!>Tf!,~'~;::'i<.:', '''.:")~~,:~~''''''~'''.'.k¡'':-:1''''.:'~",,., >.:';:~\.;.¡(;'" :';';'L~i~", ',,' .....,.¡,...,. ppg ppg ppg ft ft ft eonnection Gas and Mud Cut ft _ units _ ppg ft_units _ppg ft units ppg units units units ppm ppm ft 1" m ....' ,"", ': ,'.. L _ ~', " ·lo· .. ~,i - ~' " t.''Jt¡1:.~.'1:~ %)LCM ~'O ;·'··,,··~i:,·.tt.1('~·~ " ....... % "I, .,"1" . ~·.I·,J:~~~,i·;·.r.··f.~:~.·....:· ':':..','¡'~,'¡:¡":a":"" .;(,' -~'r;.;~:s ' ..,;,. ,~' % Current Lithology: ,; ':'~~:'~i; ;';"~~-i~'~~~"~)~' ,~~:' -'~,:"",·:~'J.~:~:U~\'¿~;~,j;A':~ .Jt,:'::~' O-~~~!:';~~-::1~~~i~:-'~~~~~ ,(..i..:"'~':;"'~'~:' ·,I'-'~:':"r~, ~\ ~'::~ ,~,;'~,ui~' >'~'~'-'¡,:" ~ ~;: i:-":J~\I ¡'.f;,oJ'"~,,,,,, ~·t: " ..,'"\"'h:../ :_~ .'{~,~:" ~:. .-.:,. ::,.,; '.;'; .~~,~~.;,..::. , ~,.;"...j ~~ I .. ;"" ," ; "~;, ,~. , r,l'''',~,~ '. . "",. ". ' ' ,~.,.\,.f.l ',~ "':"~'"::' .' . '~I' .,il ".,!4·. O' ,0 ,~.,..~ I '..,' ',. '~' ~:'!', ~'~'~'1"":'~~~ ~~(,~ 'j 1:,~\I'.;,f'~~"~'·L~"~~'~'·" ':oJ'"' ,-_,,;,,./.,,,,;,,_~~ '",:' ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to 48000 ( 0.7720 o 2 X 14 TFA: ---- na Footage for Bit Run Jets: 4 X 12 -- Total Revs on Bit: ppg ppg ppg units units units ft ft ft ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: 8 1/2" 0,0 Bit Size: Hrs. On Bit: DS70FNPV 120 Type: RPM: na Bit No,: Wt On Bit: 4 --- Visc 50 secs API filt PV 25 cP YI 24 Ibs/100ft2 6.2_ ml HTHP ~ Mud Wt at Max Gas ~ ppg GelE 10 1 34 1 56 Ibs/100ft2 pH 10.0 Sd 0.25 % 12.80 ppg 12.80 ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 60 spm DH flow gpm - Gas* 186 units 20 u n it~ ( 186 units @ 00:00 hrs, ) Pump 2 60 spm Total flow gpm - Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP 247 fpm - Pump Pres 2500 psi AV @ DC 418 fpm 17 12/8/2002 10,743 o Drill Out CMT Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sper~v-sun DRILLING SERVIC:ES I :I.'.;;¡.'l I" :~': i:ij/ ( \.. ( ( I I I . , . * 10000 units = 100% Gas I n Air Logging Engineer: Tom Mansfield 1 Reg Wilson . .' 24 hr Recí Drilled to 10992. POOH to check bit, repair pump, and change out MWD tool. Replace damaged stabilizer and flex collar. . "', ,''11'.': I .~. ~.::.~ .',.-', .~...~~<,:~~:':'", :',~,'~"_'~':'~':':~'~~~ .~:t..,:.;:"'~,) ..' ~ ,..:.' after Gas during before after .. ~'.}.. ~~, ~ :: ,t~ : i. 24 hour accumulation of Steel Filings from Possum Belly Magnets: 22.4 oz. Description of fillings: mostly fine slivers, chunks and filings. Hard to clean, lots of mixed in cuttings exaggerate volume. ppg ppg ppg units units units % Lithology Sst 81tst Sh Drilling Breaks to to to to Drill Rate during before Depth ; ,., ".~ ,"'r, "":;1 i~"".I\¥~\~,~~!j.¡>ft:'-'"i"I!,~:':~;'¡j:4i:~~"~·'I:ì;$-;:',"··~.:'i.:.: ";-. ,~. ,,;··~-,:·,~::,~r.p)~~'\~;jt;¢i;t~';Ö;~".1; "\,r-"':.;:<:.:<'.-r;::y, y.... :,:.,,' '''', ~,,_j....'~~i::!:~ ~ri~~ ";¡;)';:.;:,rr ,;".: . ;¡'r';' -::1<,:" '. :,.' ".,'«;,.J;;"i,¡¡~:t ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft units _ ppg ft units ppg ppg ppg ppg units units units ft ft ft I I . I; I " I %LCM % % 20 % Siltstone 80 % Shale Current Lithology: ,~, ':.' ,': .:";"~':'" ,'j':",' ·...i:·#!"(::·::',,·\::O<~':::: J,~'..:,:¡,~", ';'." '.,,',.;:. ';,~'::", ". ~;:";;~"$,,:*,""1~~1/,~1::::~~:",,';',"',,':"':':""'· ..... !: '. ::,r . . ·,.'~.~..:.:','~":':,,~~\,,'fk,~"~~· .::\:,:";.~~":,,,-','):'''-''''''''' f" ''.: '.iA$f~v: ~",:,~·,'t;' : ppg CI: 48000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft , ' Mud Cut: Mud Cut: to ¡ :, ;,'. :. l' '-'. ,,'~:, .:~~'~, .:' ".:9<" :~..":, },' >, ',. .". ,;' . , . . TF A: 0,7720 Footage for Bit Run 249 2 X 14 -- 86K 8 1/2" Jets: 4 X 12 -- 9,9 Total Revs on Bit: HTHP ~ Mud Wt at Max Gas ~ppg ~ 1 ~/ ~lbs/100ft2 pH 8,3 Sd 0,25 % gpm gpm fpm fpm 5,6 ml Gels Visc 48 secs API filt PV 23 cP YI 24 Ibs/100ft2 ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: ,;: . .,' I '.'~"'~ , 'oJ ',. " . ~ ....: ': ';.";.'. I I ',,'.' Bit Size: Hrs, On Bit: DS70FNPV na 4 Type: na RPM: Bit No,: Wt On Bit: 1 I eurrent 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr 25,2 ft/hr ( 73 ft/h r @ 10966 ) Pump 1 spm DH flow Gas* units 50 unit~ ( 103 units @ 10861 ) Pump 2 spm Total flow Temp Out Deg F ( 100 deg F @ 10990 ) Pump 3 spm A V @ DP Pump Pres psiAV@DC 18 12/9/2002 10,992 249 Trip Polya / Dinger 12.80 ppg 12,80 ppg Mud Wt In Mud Wt Out Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report n_..._______,.._... ___,_.__ o A I L.L IN G 5 E A V ICE 5 spe.--,.....,v- SUI' I I .',.1'.'.. * 10000 units = 100% Gas In Air .' I ~.'~;;. .~,~; f.,% ppm I I> ppm j.,:, ''¥ ft :~ "1 - ~ pp~·"~IJ ppg ....,. ppg " , ~".:~.'~~, . . . ~,: ._ 1 ~ .'. .- Logging Engineer: Tom Mansfield 1 Reg Wilson 24 hr Rec¡ RIH to shoe. Wash to bottom slowly.drill ahead fro 10992' to 11185' md. Top of Kingak @11155' MD, 9849' TVD. -. ' :'-.' . . ~.. ". ..:' '. ' . .~. :::;. ., ". -, ",. : .~, ~'; .,.,:' :~"":~,~,,~~1.I(,,~".I:'~<''''''~\::¡)+''''. :.- '", <"'" ~',:·~-::7·:,.:;"·<·'.·::..;'~",,~·. ,:"'¡~,r~"~"'~<¡~: "'~:'~."~:~ '.:,' after Gas during before after 24 hour accumulation of Steel Filings from Possum Belly Magnets: 21,6 oz. Description of fillings: mostly fine slivers, chunks and filings, Hard to clean, lots of mixed in cuttings exaggerate volume, % Lithology Sst Sltst Sh Drilling Breaks ", " ; ft ft ft Connection Gas and Mud eut ft units ppg ft units _ ppg ft units ppg to to to to Drill Rate during before Depth ppg ppg ppg I 1~·.~.~J~~7¡t~,':::iJ.~~,~~.~~·~·~'YJ·~~:~~~~¡j~-i·-<·~ .,¡c~'~':" ~~ ,\\.:, ·.'·_q}~;';"~~~~~~~~~~h~,~·~·~.i.;.~~r~~·:·~).·I·~:~: "."~"·:·~l~i~~fr··,~':· 1\'·.I~~f·.~.~~I. \.,,"".'~~~.. -:,~"\,,,. . units units units ~'oLCM units units units ft ft ft ^'. . . .;,.' . :~.~11~.~~';'; ..~"";' 0/ .0 % ··1. ·'·",·f. -r.".,......,..'.,·.-:....~.~~:.,·~'tI\; '.!J:~'~' ~.,.,-, 80 % Shale Current Lithology: I '.~ ,'.'''' :..j1"~:' :-...,~I~.~..r.,",. : 't~pIA " . .- .c r . '~.~ . '{: .... -. 20 ~ (¡ Siltstone ppg CI: 48000 ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to , ..' :.." ".\";- .,J.f.:........ ~:' ,'~~.:,;.~ .:."' .,'L·, :::~~ ',:,,':..~ .~~",;. ~'\".:~..~: '}' ....;,·f~,~~ .,1: . ~,. ;' ",>; ", ~ ..I·~.,~t~·.i;t:".i.;;~<:"!~ ~"~~~~"':1,., ',:'~~Yl~t; ':-'lh~~~': ,\: ,~';\~~~::... :.,~:'. '~:-,.. ·t" .." ::,--'~, .;~~'~~Ã1~,~tr"I,'~,1L~~.:',. i,',: ¡~~:I,~~I·';". ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: ':¡"/-t."". ,. , .~".,\:,~:?-. . . ; ',"~':-~:":f,.::-."',':': \, . . .:" - ., , .~ .'.: ~~:....~ "',1" .'~. (~.,,~:. , '"~,. ~~ .:. ¡ .~......' ~ /, ,.'.~.."¡. ...~ " .:. "."'::' 1,-. ~ '.'. .,'," I TF A: 0,7720 Footage for Bit Run 192 2 X 14 -- 40,9 Jets: 4 X 12 -- Total Revs on Bit: 8 1/2" 4,6 5,0 ml HTHP ~ Mud Wt at Max Gas ~ ppg Gels 10 1 54 1 79 Ibs/100ft2 pH 8.8 Sd 0.25 % --- Visc 64 secs API filt PV 29 cP YI 31 Ibs/100ft2 Bit Size: Hrs. On Bit: DS70FNPV 152 Type: RPM: 4RR 20 Bit No.: Wt On Bit: I 12.80 ppg 12.80 ppg Mud Wt In Mud Wt Out Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Current 24 hr Avg 24 hr Max Pump and Flow Data RO,P. 107 ft/hr 57,9 ft/hr ( 109 ft/hr @ 11180 ) Pump 1 64 spm DH flow gpm Gas* 93 units 56 unit~ ( 114 units @ 11148 ) Pump 2 65 spm Total flow 540 gpm Temp Out Deg F ( 105 deg F @ 11035 ) Pump 3 spm AV @ DP fpm - Pump Pres 3030 psi AV @ DC fpm 19 12/10/2002 11 185 192 Drilling Polya / Dinger I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I sperr'y-sul' CfR ILL I N G 5 E A V I c: E 5 I Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas I n Air I .~, ~, ,'~<) '" ~~ :~'''', 24 hr Recé Drill ahead from 11185' to 12469' MD. Top of Sag River @124491 MD, 10818' TVD. , . '~'" ':. ö . .' ",'~, I.~ ..~.~ ;~ ~,I ~¡":;>":'¡~' . -: ,,'.~';r;~,! "" ;<" ~~,: . 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.6 oz. Description of fillings: mostly fine slivers, chunks and filings. Hard to clean, lots of mixed in cuttings exaggerate volume, .1 ; ....:. .~ % Lithology Sst Sltst Sh . I '.~' ..tl·.';':-:'~"/: ~ ,:,'_":I.:~ ':;'.".,,}¡ I,' , :' ~. ~'II "'¡':"¡, units _ ppg units _ ppg units ppg ," ,'.' ",,:.,,' ';..-<' 14:' \I %LCM to to to to after Gas during Depth Drill Rate during after before before Drilling Breaks . ":~'..,,1;:~ :~~. ¡:;;~1Ï'iJ}::t,~ïï:ii;';\~{~d!;.tW~',:¡¡':ï;1i';ftf~i~~'~ .,'1,"1 :~'i':, ',..:' .....,.'?;::-.1f*Ji,ij:'f:~'¥rj~\I'*;H,';·:,:::· /.,~ ;:!!,,~jI~-:: :.:it~r"~;\¡j""q.;;'¡'jJ·'O:!\';~\',~,;,; '. j:.i$~~";:'~:f.>.:1':I!ri.::·~·' I ft ft ft eonnection Gas and Mud eut ft units _ ppg ft units _ ppg ft units ppg I ppg ppg ppg units units units ft ft ft . ., 'r~ .~:' _ .. - -. ~ t. '. ;. .' '; . . ..~ .... '''~~ ,. . .~..~. .'.~( ~ ,il .~.. '." ':..-:( ( % 3andstone % Current Lithology: 70 % Shale 10 20 % Siltstone .~~,:~~' l' :';";'~'i,'r :',',:, -",:~ - ,\.." .J;. ,~'. ·~t\j, ,f('~:~" ,~:¡," : ~':} ':'l~·~f, ", ",,': ". ,'~ ' '~ ~~:" :::~~,,~~:,';srf<~~ ,'\~?,;~'t~';~:~'-'j~~':i~ ·"J:1·':~~~";¡·.~''',~.t"·~;'·(:'":~~r',i'~ í; '~:~:'\,'~~~'~,::~)~~:l~·, ::;.:" ",~~; ';' ~~~.~' ";"~I:t !.~" ~i(/::~ ":., ~;;~' ·"'~f)'}~\~,;l~'~;~.'~i·: ,f"!:: I~.r ":~:.i 'j} :: <.'..~~. .~r~ ~~,'-~"~'~' ';:,;.' ,~t\ ~;:~,'!t'.", .',.: I ppg CI: 48000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft " '; ;',;',".':: Mud Cut: Mud Cut: to Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to ..:. '... ".;::/:~' ~\'~<"...:' ,:i~J-"':;'+:;:. . ¡:~~; "",~'~'~·i:..~~: .;~".; ", ~!:~.,,:~I;{~;...';;.~l:!.~~~: ;·,~'~k¡·""'.'~. / .( '~',:, .~..~,~ :~.~.\it;i),:oc" .~.'.' :~~<.~~.;~~:r, }:;": ç _,' ,.<".~ ,..' '..: ; : '. '.$ :¡.::.,......:~ ;.~ "~':,-'J~ ':- ~';~.~'.~ '~.. TFA: 0.7720 -- Footage for Bit Run 1,476 2 X 14 -- 117,8 Jets: 4 X 12 -- Total Revs on Bit: 8 1/2" 13.5 Bit Size: Hrs. On Bit: DS70FNPV 150 Type: RPM: 4RR 23 Bit No.: Wt On Bit: ( --- 4.4_ml HTHP ~ Mud Wtat Max Gas ~ppg Gel~ 14 1 64 1 88 Ibs/100ft2 pH 8,3 Sd 0,1 % Visc 54 secs API filt PV 28 cP YI 34 Ibs/100ft2 12,80 ppg 12.80 ppg Mud Wt In Mud Wt Out I Current 24 hr Avg 24 hr Max Pump and Flow Data RO.P. 24 fUhr 85 fUhr ( 162 fUhr @ 11280 ) Pump 1 64 spm DH flow gpm - Gas* 94 units 110 unit~ ( 274 units @ 11618 ) Pump 2 65 spm Total flow 540 gpm Temp Out Deg F ( 110 deg F @ 12340 ) Pump 3 spmAV@DP fpm - Pump Pres 3150 psi A V @ DC fpm ~ 20 12/11/2002 12,469 1,284 Drilling Polya / Clump I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: I Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: D A I LL IN G 5 E A V I c: E 5 spe....,....,v- sun : "'., ..:', ..:: .j. ,:III.,¿ * 10000 units = 100% Gas In Air . , '. ~. , ~ '. . ~', ~:,.'" ." . "..... '~.. '~,:, .......' ,¡''!'.... , :' " .:"." ~, . : ~ " Logging Engineer: Mark Lindloff 1 Reg Wilson 24 hr Recê Drill ahead from 12469' to 12487'MO. Short trip to shoe. Trip out of hole. Lay down BHA ??? TO 8.5" Hole @ 12487' MO, 10845' TVO 'f~~:;'r~~:,"'~~~·.~:':~' ~'_,.' :,J... .,;'{;" .,: .','.~" .~~ '~, '\.: . :.', .~~ 1 . ':'. \':, ~C~:,':> < . ~.,'~,.. .,' ~,'. .::" }'.: : ~~':~;{'>;~'.~';.":~(""~: :_~:~:,~ ,~:~ ;',:,~~~~~ä~~' ": '~~~"'~' ï~~:~~ "';":,'~'-!~:~~ i' .\ ~":' 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.6 oz. Description of fillings: mostly fine slivers, chunks and filings, Hard to clean, lots of mixed in cuttings exaggerate volume, % Lithology Sst Sltst Sh JIØ'.i, after Gas during to to to to before after Drill Rate during Depth before Drilling Breaks eonnection Gas and Mud Cut ft units ft units ft units ppg ppg ppg 1 ppg ppg ppg units units units p( "~~~, ;~t~~ ·1:,,';;:,:','·,(11.',:::. ~~: : . ' : , f .~~: , ;" "~Ièc"··'I¡;·~H<\*,~~~~~~~{~~;~>t,*Jl':~'~\W&'1~!£àt~i¡::~'+,r~~,'~~I!tll~h~M'~:'~;~$i:.·(,~t.'I!.¡~i~{~~,!J'~'.!¥~V,I:'f,!:~y,þj ft ft ft . ·."f,~1 . , %LCM ft ft ft ppg ppg ppg units units units 1 . ~ .~ I.:r,. .' .. .1..' I.:, % % 3andstonE . ., ;','''' '~"'",; ~ ..-" ··~..iI.'1_f . ·"~(I. ". ·.r· ~.' ~.t'''\..'I'\ ~ '.4 ,.',.......,:.... '~'..,..~,:; '=""'. 10 70 % Shale Current Lithology: . .~.:;'~._-r:~.~_~~~ .\.'..'¡~~.¥,~¡~~~b~~.(~~~~-~;~~~f~~t:~, ,>~.~::~~ ~~~.'::.:,(>:',:~!~~':~J/~::;" .~J,~:~~..~~~:,~~.~\'~~~.\-k.'..'~ ~~~~,~"J~~'¢'~..~';:i,~~, t·~~~\,J~~~~~.~~· ...~.~;.. ~:+~'. .~~ ~'tÄ-:'~.:~:~,~ ::;. :':..' ·~:~~-r~~·r~~.~i~:~:)~~> ~ ,,:. ,~', '~: ~:.,~ r' ..~ <":......:~~ :::~,.. ~.~...::'. ":',i';, ~ ·I:.':~~ 20 % Siltstone ppg CI: 48000 ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft ..',(' ~. . ? Footage for Bit Run 2 X 14 Jets: 4 X 12 -- Total Revs on Bit: 4RR Type: 23 RPM: 0.7720 1,4 76 TFA: --- Mud Wt In Mud Wt Out 4.4_ml HTHP ~ Mud Wt at Max Gas ~ppg Gel~ 14 / 64 1 88 Ibs/100ft2 pH 8,3 Sd 0,1 % .~: \ ~ .~ '" ,n -- Mud Cut: Mud Cut: to Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to ~~ ~- :,~-:"r""..fo..,,~"'~;;"'. ,,_~,t. ~'.' .;." ~ . . .,'~"~ t.~~,':~'. ',. I· ,',~~.,~~':'::,': \,<, ,J::':'\~~~'.:",'''..'::->. . '~:',\',,~. -., .,1"-' "r-.I,;:-: ~ ' 1 .: '.i~.: ..;',....',.- r~'-'" :~".~~.,~:,\,~,,,,.;:, :/.".~",';.~ 8 1/2" 15.0 Bit Size: . Hrs. On Bit: I DS70FNPV 150 Visc 54 sees API filt PV 28 cP YI 34 Ibs/100ft2 12,80 ppg 13,00 ppg ( Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. ft/hr 30 ft/hr ( ft/hr @ ) Pump 1 64 spm DH flow gpm - Gas· units 95 unit~ ( 135 units @ 12486 ) Pump 2 65 spm Total flow 540 gpm - Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP - fpm Pump Pres 3150 psi A V @ DC fpm Polya / Clump 21 12/12/2002 12,486 17 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ( BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Mudlogger's Morning Report r Customer: Well: Area: Lease: Rig: Job No.: sperrv-sul' DRILLING SERVICES I sperr')I-sun I:J R I LL-I N G SEA V I c: E 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 22 12/13/2002 12,486 o Circulating Polya 1 Clump Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. ft/hr ft/hr ( ft/hr @ Pump 1 69 spm DH flow g¡::m Gas* 65 units 71 u n it~ ( 428 units @ 12486 Pump 2 69 spm Total flow 571 gpm Temp Out 120 Deg F ( 120 deg F @ 12486 Pump 3 spm AV @ DP 112 fpm Pump Pres 3425 psi AV @ DC 524 fpm I I Mud Wt In Mud Wt Out Visc 50 secs API filt PV 32 cP YI 37 Ibs/100ft2 3,8 ml HTHP 9,8 Mud Wt at Max Gas ~ ppg Gel~~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8,8 Sd 0 % w. Current Lithology: 70 % Shale ~ % Siltstone 10 % 3andstonE % ~!óLCr...'1 _ ';',: ~t~~·~I'··:··:'''·~J:''!(\'~~·1·-:;iÞ:!i~!1'''':m'f~.A.J'WI:~t.J~'J._i;;f¡¡'!~';'.!\1~".(~:~K!i1~~~~~.~~~J'1!~ì'~¡m£\~~i\~1:4.j~:~f,'~~~~·~·}'·,'i3;"":,:,,,:·:::t:';':á.·'·A:;;~':"'~"\I!b·, . I Connection Gas and Mud Cut . ' I It units ppg It units ppg It units ppg .I~ ft _ units ppg ft units ppg ft units ppg ,.. ',: :"/..~",.r_i .,,'¡""'.'~~JU.~~i~;I',..t;,-:oI.>~~ :~t.,~~~",,":;,.., "." :. .,',j.,.·,..:,.':',;,:,·,,:-7::u:i...,~;-:--M~~j~~~~:'.~io;:(i!i!'_~\(::.,:~~~~.,~:, .'_:'I\";;';-.,.!,~~ 'è..:.:~~<".\.~.1' Þ: :,..r· U~,i~S,:; o. ";0' :,.,; ",I,' ~~~~.¡a: 13,30 ppg 13,30 ppg Bit Size: Hrs. On Bit: 8 1/2" 25.0 Jets: 4 X 12 2 X 14 TFA: ---- Total Revs on Bit: ? Footage for Bit Run Bit No.: Wt On Bit: 4RR 2 Type: RPM: DS70FNPV 66 1 .;.<.¡!.: ,:.:~"~..:.:...... '."":'~.. -';. '1''('',: '. '. : ',.,1;'" '.. ".... : '~>. ...~,. '.~;.:.I"'::l..Y~"',.:.",J...,t '\".·~··'''·~·::·~·I:,j·.~~":·:,~.,,.~·· ,;'. ,,'~':;'\.:c~, ::- '\-"".~~~¡).j.'... ",'1" ....~. ~ ~ ~ ,". ~'. ' Trip Depth: Short Trip Depth Tight Spots: 12204 to Mud Cut: Mud Cut: to ppg CI: 51000 ppg Short Trip CI: Feet of Fill on Bottom: ft Trip Gas: ft Short Trip Gas: 12015 to ":,' , ,.y.' - .·,,'I.,....(~·.'~.~r~1[~~;.':·~I, ,~.:,..~"';,..:..,. ~...:~tJ: ,',' "I .....:.:~. ;1- >..: .:-}f~"'~,:",;,~~;., .~.;:.."'~;.¡:.:ä~'.'":'''~~ ,:.~II"f,t.·.~~n·.'·¡··t'. '; .~I"-~-!\. .;: "'I;;'::~. ',~~I'"'''''''' .~}tA:;I~·' ,~1~"\ 1 1 I Drilling Breaks 1 Depth Drill Rate during Gas during after % Lithology Sst Sltst Sh before after before to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3,6 oz. Description of fillings: mostly fine slivers, chunks and filings. Hard to clean, lots of mixed in cuttings exaggerate volume, """, .\ ... ~~, :~i:, .:' ~'I~ ':~:f':' ,;:.~:~i'··¡·".h.!'r.Ji:;·~;.:¡ '~',.~~;,~~~::':\.' ,,\,~·,~{~··~',·~:~'~:Jt'~;:\'~.~':t.·,~ ~ 'V::/":'?f~"~:~ ~!;;';f~~~·:~:'t~)"~!'t,2'R)~~1~.,:~~i, 11~:(~l:~".'~:f:"'~":-:: ':~. ~'~i,~'k·,:' ~,,{,;:~:,,;,: ~!;~":':\:" '"~·:v·'~:r'·';'·,;;~V:·i:~'~~·'~ .~~ '.¡, !~~~, £.~,~ '"': ':~'. ~,"¡: . "'. , 24 hr Reci Circulate 1.5 B/U and started wiper trip, Pulling tight to 12109, ream up to 10584. RIH to 10700' tight, ream to bottom 12486. Moderate amounts of splintered shale to the surface, weight mud up to 13.3 0,7720 1,4 76 .....,. ,-'. .. ppm ppm ft * 10000 units = 100% Gas I n Air Logging Engineer: Mark Lind/off 1 Reg Wilson .! ~ ~ : .,~...' . \,-..( "'1', * 1 0000 units = 1 00% Gas In Air ~ .\'. 'r:~ ,,'. . ~ .~~ ."~' '."';"/~'~-::'f' ~'~, ~.,~:;\~~~,~:?:~, /-" ..... . ~ ~q ~:'!.'~.~·~'!.~~3·~.,¡ .-"... \. Shublik 12632' MO, 10953' TVD Ivashak 12730' MO, 11028' TVD ~ Logging Engineer: Mark Lindloff / Reg Wilson 24 hr Recê Drill out cement shoe and 20' of new formation. Ran FIT, 11.5 PPG EMW. Drill ahead to TO 12886' MO, 11149' TVO. CBU, start POOH. .~ '. ~I:I, ',:~.lt·t~~f~1~~~·,\·:o:~·'~'·: .:':,..;: :::'t~~~i~'~" ?i~'·~':':;~;f.Ç,,;'¡-7~:<~~~~~I~:~'~;~~~~'.'?~r. ;~~';tt~!·~: ";'~:1i~'¥~~:~~\,*~\'b,rt~f ~~:,;'J~~ ~~,}:~1~:'~\:IJ,\J.~:Y~' .:,~.~~..~";}:.}~~'\'~>,~ 1':"-: .t<,"'. :';.~:-'?~.~i¡~~:;[~·~~·~ 1·'~~,;'\-:':\~;'.~·;'·.·I""";r'·~.("·~~·\:' ~':. ,: ,. ?'. '~~"~~"~"'" ' {i.a" ·'rl ~t ;'7 ~.Jñ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.6 oz. Description of fillings: mostly fine slivers, chunks and filings. Hard to clean, lots of mixed in cuttings exaggerate volume. ':.... .' % Lithology Sst Sltst Sh "",~" I " , { ~.<:' -;, Y~.'t..~~..,~.., . ~'~~: I~/~~~~I~.f~:;~~~:..~...-. ~ I ' . , .:.~ ,~·,~~~f~7.~~...;~·. ~.: ,. ,'::,':'.., :~.' . ::;.:.~~ :''' ¡ :~ ':.~.. ~ ~ '> t, . I.., ~~ after Gas during to to to to ( before after Drill Rate during Depth before Drilling Breaks . .....~ ;",:,.-,~::-: ~~";:~~"~l,<''';I.!~'''''~:::'~'.;.¡;'\01?!,~}ié'.,f :.: ':,. '~''';':'',~ ,j,,,:,~"'·:.:/~,~~t;"i"ð.~~"+1\ti4f!r:·):;:ij·~."fjJl\~:~~::·<;\~~;,..;þ:::1¡:."';I,:{~~,,:":..,,:"'fj¡l.':~~,:.,.:,.';!'·.:--} 1...._...:..:....,. ,."...., ¡' "',"-..' ,.':-: "¡,.,c· if , .,,':.\\i:i , , .¡ ~:) I,,: . ppg ppg ppg units units units ft ft ft ppg ppg ppg \', ..1' Connection Gas and Mud Cut ft units ft units ft units ppg ppg ppg ( units units units ft ft ft II',",';:, ;~ -.,),',:, . ~'oLCM ,. '.. ""'I'!.oj¡:fll~!(~~.';"",' .,;.t'..'..., ....,,'. .. . % . .;. '-~:~ '.;'''(:; ~"~~rl:'~.~:'.~,-r.j!",-~.~:,"".:,:~" :.,.,.,.~, ~~~.~.~(:.~--.t.~...~.~.: ";'j"'''' 1:,-~'-:''''''~''·~,\~,..~~:W~!I~~\~'~':'~c " -~(J"~~\:'¡·"';·'~'.i~j·~\"~·~~~~'t'i·~':"ó7-·~· 20 % SST ppm ppm ft 18000 .~ :~:.\.:"~' "¡,:;,,: ::: . ::;",~:'i '. ~ """. ~,-·.J.J7J~.f~·:,¡~tf~f (~::~.'~':.~~~~. :".;'~..~~-:-: :~~:--t.-:-- :~,:~~,:,:,:~.';:·'"~~')f1·')~ ,:'--f~¡~''-::~'~~~,;''~'.,~ '.~: .~- ,r:,~.w..¿{·;(~ ·V;'·.*·~'~,,,·;:.':?·,~ ':"'. ~~.., : J.~:x. ~~,;,~.~:~,.:';-'~. ': '. ~. ., r~.' ,: 1 %) 80 % CONG Current Lithology: 1 ;'.,',.- ~~.,':: "'. '. ',,,.. .,.',~~~':..:'.~ .~.':.·,,".~·I'~' .:·~;·""·":...,."·,Y·:~~~f~~~"'~~,.::"'~J=,'.':'~'~~·""~: ;......~:'.., ...~1G"Itä1'.. 1~·f..:1I,Ð,·i.. :-...:.'...~.~'~:"'~., :" r.·., '<",.. ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: 0.5180 400 TFA: Footage for Bit Run o X 0 -- 139 Jets: 3 X 15 -- Total Revs on Bit: ( Mud Cut: Mud Cut: to Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 6 1/8 15,5 Bit Size: Hrs. On Bit: STX-30CD 80 Type: RPM: 6 24 --- 9,30 ppg 9,30 ppg Mud Wt In Mud Wt Out ( Visc ~secs APlfilt ~ml HTHP ~ Mud Wtat Max Gas ~ppg PV 11 cP YI 22 Ibs/100ft2 Gels 10 / 13 / 14 Ibs/100ft2 pH 8,8 Sd 0 % Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 40.5 ftfhr ( 165 ftfh r @ 12487 ) Pump 1 0 spm DH flow gpm Gas* 46 units 166 unit~ ( 698 units @ 12538 ) Pump 2 85 spm Total flow 302 gpm Temp Out 94 Deg F ( deg F @ 12486 ) Pump 3 spm A V @ DP 125 fpm Pump Pres 1910 psi A V @ DC 495 fpm 24 1/19/2003 12,486 400 POOH Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 hows: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Mudlogger's Morning Report I Customer: Well: Area: Lease: Rig: Job No.: spe!l"''''''V- sun DRILLING SEAVIt:ES I,...· .., ".' ..... .' ';.~ ~'~ ...r.:- ... 10000 units = 100% Gas In Air . Logging Engineer: Mark lindloff / Reg Wilson ·<\""I·~~":,:·;)t. ....'.. Continue to POOH, Rig up to run 4.5" liner. 24 hr Recé ...",...;,,:....~ ('. '" lC1',)~" <',/'J'.:.J:.:. l :L: '''.:~.: .~ . I. ~.' :¡t.')~':''!~, :~,~t;)~~: . ." " 'pl,:~:,:,,,,::~.,,;~'.:;'~~,,,· .~':',' ~""~;<'''l:.'/~: ;~fi'.':>1. t: ~~ {~', }~';~h:'.::,:~~:· ~:.i. .~·'I ..~;.~.~ ~,~ti:~{:¡'::J~~~ ~t",~~,~~w;:~:·~:;;f~::r:.·:,:" ,'".:' ". .", . 'h:' ~':', . 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.6 oz, Description of fillings: mostly fine slivers, chunks and filings, Hard to clean, lots of mixed in cuttings exaggerate volume, % Lithology Sst Sltst Sh ppg ppg T'f' ppg '¡!!I" , : . I..·"":~:' ~..~~\~ "I: I :", ~, '! I" ""~',:':; . units units units to to to to ( after Gas during Depth Drill Rate during after before before Drilling Breaks ~'''~'fJ ~....;, ..\~:i!.*~~¡ìfi~~~·,,~:4!W~"'·,~ .,J,t·.~:';bo~~~~"'n~~'~".:..f:'.·' '.~':~~r.r I,h ~~(:~';.~1t-I-4.': ':~·W~·~~~J·_~':f,,~~.:::.~~' ~il ~..~... ."~.,,~~'~~~~þ'}~,~1~'"f1p!!1'~ "-'.If'" ~..',.> ~~." "'::''.I"*r~·~~~:_~·,:,· ·¡·.l'J,r·:. Connection Gas and Mud Cut ft units ppg ft units ppg ft - ft units ppg ft units ppg ft - .. ft units ppg ft units ppg ft ( : ¡'~'~.:,; ~ ~~;t- 1:1' ~.1~~~:~¡:ì~~;'~~~}-~~~~~~~::\\-~-Þ"~;ñt~~~~~~~~~~~}:'1.f4~j:.~'f 0~,i-~l~~-.7-"V::f..:·~~~~~'tJ'!é;,~~~~r~? i~:~-':~~.~~~~~¡':"~~~Ñ:~r:~a-,."~~- ·:,~"~~~~~:-'~*~~:~~~m~"'¡ ~S!·'~~'",·~;,~~· ·~_~~'·~':;"t·.~~ '>~ ',;t~~ ..~,~:·i~~~.'·~·\;~j:;...~~<~t'~~·,.;.",!:J,; 1 Trip Depth: ft Trip Gas: Mud Cut: ppg CI: 18000 ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - - Tight Spots: to to to Feet of Filion Bottom: ft #ì!J¡\I{__'t~¡4k'IJI&..tt~~ØiØi~,W¡f*IXWiMí¡Æf&~_!..~~itå&1!8t~%M~%\$U~Th1i~(~%\_fif.~~_¡~i\¢~¡\ît!Mmt%~!li4{fW¡:¡\\tjéM!i!. Current Lithology: 0 % 0 0 % 0 % % %LCM , "~";'~; ,',;':: ~..' ¡,' ~. .'-. ~ .,; ~ ,...~~",. :'~ ~" "':... ,. . f>-... . u; ..'!.i""~..:: ··i.':~~: :.:" .. ",- \r~~"{~~l~'''''';r'·~ I ,~~. ~:' ~ .': :;.., j~",~.. ~-'.' ."'::'j" .";;'¡:'~,~\. 1 .', Mud Wt In 9,30 ppg Visc ~ secs API filt ~ ml HTHP 9.8 Mud Wt at Max Gas ~ ppg Mud Wt Out 9,30 ppg PV 11 cP YI22 Ibs/100ft2 Gel~ 10 /~/ 141bs/100ft2 pH 8,8 Sd 0 % Bit No.: 0 Type: 0 Bit Size: 0 Jets: ~ X ~ ~ X~ _ TFA: 0.0000 Wt On Bit: 0 RPM: 0 Hrs, On Bit: 0,0 Total Revs on Bit: 0 Footage for Bit Run 0 ( I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P, 0 ft/h r ft/hr ( ftlh r @ ) Pump 1 0 spm DH flow Gas* 0 units 8 unit~ ( 84 units @ 12886 ) Pump 2 0 spm Total flow 0 Temp Out 94 Deg F ( deg F @ ) Pump 3 spm AV @ DP 0 Pump Pres 0 psi A V @ DC 0 25 1/20/2003 12.886 o POOH Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ( Mudlogger's Morning Report BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Customer: Well: Area: Lease: Rig: Job No.: spe.....,r-"V- sun DRILLING SERVIc:es I sper'r'y-sun DRILLING SeAVIc:eS Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 22 North Slope NorthStar NS 22 Nabors 33E AK AM 22184 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 26 1/21/2003 12,886 o Cementing Dinger/Holt Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P, ftlh r ft/hr ( ftlhr @ Pump 1 55 spm DH flow gpr.1 Gas*- 171 units 100 unit~ ( 410 units @ 12886 Pump 2 55 spm Total flow 0 gpm Temp Out 94 Deg F ( deg F @ Pump 3 spm A V @ DP 0 fpm - Pump Pres 706 psi AV @ DC 0 fpm ' ( 1 I ( Mud Wt In Mud Wt Out 9.30 ppg 9,30 ppg Visc 44 secs API filt 5,0 ml HTHP 9,8 Mud Wt at Max Gas ~ppg PV 11 cP YI 22 Ibs/100ft2 Gel~~ / ~/ ~lbsi100ft2 pH 8,8 Sd 0 % I I ;~~11 r~ ~I~:~ I Æ~ Depth Drill Rate during o o Type: RPM: o o Bit Size: Hrs. On Bit: o 0.0 o X 0 TFA: -- o Footage for Bit Run 0.0000 o Jets: 0 X 0 -- Total Revs on Bit: .. ~ :"'~ :'1, '/. '. . ~- ",~' . ;;~:: (:..~ ~~~""." ':'~ - .,~.~.':', ';;.'·/:f:.'~~·;:~~·~8 ~ .~rt·~~i;i~~· '..:~;:.r;:\or;;"·l~ .;~ "," :~.;.s:"::-;f' ;~f';~:~~'Y'~' :';~ ;t.P~ ~~ ;"-:'it)~>(v.: >.;~!,: ~.~~:: "';,> "~r ~:~: Lr ~:;'''; ~;'~~}~";~:-.;,,-..;:, . ";':-·:.i<"·, ~,.., ::'1: ',,:,,~ ~~'f-=". ,;,'.t.~:¡.·4::.~' -, ';, 410 ppg CI: 18000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to . . . -. :'~ . ":,f~\'KJ1:~,~~~,,(~t~ ,";:';"~'.:~'::'?~~~~~tiSt/·:.~~;:1t'\~~~~..6~;'},~l(~f~.~~.¡f.~~~~1¡-"f~~~~~)~~~·,:.~~~f$'·~~~.?-~~~~~~4!~tift1~1;.~~~~~J·:~~=^;_·...~,~~?t~:.·~~~~¡;,;¿"::·,:_,.-:,.~:..,~,:.,,,,x~þ;"-~·,,:?~·:~;~.,~I'";'II:.JI:-: '., .,' ;.f'~ ," '<., ,~_.c.: '~"·~"i,~tJ'·'~~ '.'~), '::~, 'i" , .~ ."" cur:e~~~::~;::::}o..~\~.,^~~:~.~~",.", ~,:.:::;:::==::~_..,~,-~::~., ", ·::i:::'~~··~:~ 1 I·.·.'.'..:.·,·.·~.:. ft _ units ppg ft units _ ppg ft _ units _ ppg ! ';: .. ft _ units ppg ft _ units ppg ft _ units _ ppg r. ~t~;.I.~..··'~~N~Ü§f.~~g-ø:J¡~~I1'_~~;~~i-¡,tt::J,'-'$;<~"'.1J..t~~~<·f<íi.'o/;t:,~'ta.~~Ø;ti:)j:,ÿ'~(~.;'i\"'x;¡¡'~¥~~~$\ie.tlf;~Û t I I 1 before to to to to Drilling Breaks after before Gas during after % Lithology Sst Sltst Sh .' . 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.6 oz. Description of fillings: mostly fine slivers, chunks and filings. Hard to clean, lots of mixed in cuttings exaggerate volume, . ~'.,'...~:.'~'/~ 10' ': ',~. 1:,~ :'~.~~r#~:i/!'t.....,.::::{.~::r~~::~~!.~;~~·t,.. ~:~,1~,~~~' ':',,~.'''i~~~~,:'':~; '·~~':~~<~\~·:~:~~~.~~:~~·~~~;~~~!.~·,~t~~~~~~~,~i§''',~~;:~:¡;:., ,;':',,¡~~ :\,;,,....~:.....,:; ·!'~·...~*.t~~:~';",{\·~~~;:~~~:,~;:'·~ ,:,:~1!.;~~~~~:~,<~:~~~':~,1~1:fl~;~::~.¡ !~' .~. ;,'.' :'} .': ' . ' . .' .,~ '·~~1i't· .',,,. '. 24 hr Recé RIH With 4.5" liner, CBU at 7" shoe, continue to RIH to bottom. Liner landes at 12885, Slowly started circulating increasing gradually to 85 SPM. Rig up to cement, cement according to well plan, No problems. Currently circulating. Max Gas at bottoms up 410 Units Logging Engineer: Mark Lindloff / Reg Wilson * 10000 units = 100% Gas In Air :, I .' .~. '. :.'. ..'. - ~ L~:'t.~';, '.- " I ,1'( :J..\)""' I . ~ Schlumberger I Job # 40008221 r Custom.er BP ADW , .1 Well NS22 Field Northstar I Rig Nabors 33E . AFE # NSD-831326 I DD's Tunnell / Robertson Co. Men Kidd / Clump I PDM Run # 1 PDM Ser# 962-1126 I PDM Size 9 9/16 (Mud Type Sea H20 Spud BHT F '1lltem Description Bit #1 MX-C1 TFA=1.031 I 2 9 5/8 Std PDM 1,83° I Float 3 Orienting Sub I *mule shoe 4 MONEL STAB I I 5 MONELLC 6 MONEL LC 11 I f I I ,I I 7 MONEL STAB 8 X-OVER ., I ' II I i 'BHA and Run Objective ! BHA and Run Results R/S 5/6 Stages 4,0 Rev/Gal 0.113 Mud Wt 8,7 Mud Vis 150 Vendor SIN 6004906 Ana 962-1126 Ana GLDD-f05 Ana HA-016 Ana 1 O-HA-O 13 Ana 10-HA-011 Ana HA-012 Ana ANA614 BHA# 1 Date In 21-Nov-02 Date Out 22-Nov-02 Hole Size 16 Time In 16:00 Time Out 8:30 Hole Sect Surface Depth In 201 Depth Out 510 Bha Type Steerable TVD In 201 TVD Out 509 Hrs BRT 16.50 Drlg Hrs 1.2 Drlg Ft 309 Avg ROP 257.50 Slide Hrs 1,1 Slide Ft 250 Slide ROP 227.27 Rot Hrs 0,1 Rot Ft 59 Rot ROP 590.00 Pump Hrs 4,5 Rotate % 19 Slide % 81 PDM Jet Blk Inclln Az In Bit>Srvy 30,00 Bearing Mud Incl Out 4,79 Az Out 54,73 T/F Corr Rubber RM100D Avg Dls 2.8 Max Ds 4.6 Plan Dls Sand % 1 RPM 40 GPM 500 SPP On 475 Solids % 3 DIg TQ 4,0 WOB 20 SPP Off 550 OD lD Stab OD F.N. Bottom Conn Length Cum Length In lOut Top Conn 16 3x20,1x12 1.35 1.35 Jets 7 5/8 Reg P 9 9/16 Tool 15 7/8 1,06 7 5/8 Reg B 26.03 27,38 6 5/8 H-90 B 8 2 3/4 6 5/8 H-90 P 1.46 28.84 6 5/8 H-90 B 8 2 7/8 15 7/8 2.35 6 5/8 H-90 P 5.60 34.44 6 5/8 H-90 B 8 1/8 2 13/16 6 5/8 H-90 P 9.96 44.40 6 5/8 H-90 B 8 2 13/16 6 5/8 H-90 P 9.69 54.09 6 5/8 H-90 B 8 2 7/8 15 7/8 2.12 6 5/8 H-90 P 5.25 59.34 6 5/8 H-90 B 7x8 2 7/8 1.20 6 5/8 H-90 P 3.09 62.43 4 1/2 IF B AS ~xpected Clean out conductor and survey BHL ----~--_...."._--_._._----_.".._._--_.- -...., ..._--,.,. -~--._._-,_..,.__. .-.._-.--...-.-..--'~.-..'--- BHA Weight Dry Wt 10,934 Buoyed Wt 9,485 Incl Angle 1 Buoy+lncl Wt 9,484 Hrs. In 77,8 109.6 26,3 Hrs. Out 82.3 110,8 27.5 ~.5 Bit Data IADC # 115 Footage 309 Hrs 1 ,2 k Revs 4 k Grade Not graded Comment Tool Motor Jars Bit #1 Why POOH / Comments I ~ Bit To I Survey=30 p~~~.~~-~~:_~-~~~~~-~~~-_.,.._,_._-----_.- --.'. .J ,~r .).~);:: Schlumberger BHA# 2 I Job # 40008221 Date In 22-Nov-02 Date Out 24-Nov-02 Hole Size 16 I Customer BP AOW Time In 8:30 Time Out 3:00 Hole Sect Surface Well NS22 Depth In 510 Depth Out 3.725 Bha Type Steerable I I Field Northstar TVD In 509 TVD Out 3.428 Hrs BRT 42.50 Rig Nabors 33E Drlg Hrs 15.7 Drlg Ft 3,215 Avg Rap 204.78 AFE # NSO-831326 Slide Hrs 6,0 Slide Ft 1,026 Slide Rap 171,00 I I DD's Tunnell / Robertson Rot Hrs 9.7 Rot Ft 2,189 Rot Rap 225.ò7 Co. Men Kidd / Clump Pump Hrs 26,2 Rotate % 68 Slide % 32 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 4,79 Az In 54,73 Bit>Srvy 67.39 PDM Ser# 962-1126 Stages 4.0 Bearing Mud Incl Out 29.42 Az Out 22,54 T/F Corr 51.4 J I PDM Size 9 9/16 Rev/Gal 0,113 Rubber RM 1 000 Avg Dls 2,0 Max Ds 5,2 Plan Dls 2,5 Mud Type Sea H20 Spud Mud Wt 9.2 Sand % 2 RPM 40 GPM 940 SPP On 1900 BHT F 64 Mud Vis 57 Solids % 5 Dig TQ 10,0 WOB 35 SPP Off 2050 Description Vendor SIN aD ID Stab aD F.N. Bottom Conn Length Cum Length Item In / Out Top Conn I Bit #1 MX-C1 6004906 16 3x20,1x12 1.35 1,35 TFA=1,031 Jets 7 5/8 Reg P 2 9 5/8 Std POM 1.83° Ana 962-1126 9 9/16 Tool 15 7/8 1.06 7 5/8 Reg B 26.03 27.38 ( *Float 6 5/8 H-90 B 3 MONELLC Ana 1 O-HA-O 13 8 1/8 2 13/16 6 5/8 H-90 P 9.96 37.34 6 5/8 H-90 B 4 MONEL LC Ana 10-HA-011 8 2 13/16 6 5/8 H-90 P 9.69 47.03 , 6 5/8 H-90 B \ MONEL STAB Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H-90 P 5.25 52.28 " 5 6 5/8 H-90 B I 6 MWD Ana 11664 8 3/8 3 1/4 2.11 6 5/8 H90 P 29.72 82.00 *filter* 6 5/8 H90 B 7 Orienting Sub Ana GLDD-105 8 2 3/4 6 5/8 H-90 P 1.46 83.46 *Mule Shoe 6 5/8 H-90 B [, 8 MONEL ST AS Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 P 5.60 89.06 6 5/8 H-90 B 9 MONEL DC Ana NMDC-HA-023 8 2 7/8 9 5/8 H-90 P 30.83 119.89 {, 9 5/8 H-90 S 10 MONEL DC Ana NMDC-HA-02C 7 15/16 2 13/16 6 5/8 H-90 P 30.91 150.80 6 5/8 H-90 B 11 MONEL STAB Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 P 5.49 156.29 I I 6 5/8 H-90 B MONEL DC Ana NMDC-HA-017 7 15/16 2 13/16 6 5/8 H-90 P 30.83 187.12 12 6 5/8 H-90 B I 13 HYDJARS DAILEY 1417-1044 7 3/4 3 1.19 6 5/8 H90 P 30.83 217.95 4 1/2 IF B 14 26 Jts. HWDP 5" NAD 26 HWDP 5 3 4 1/2 IF P 780.65 998.60 4 1/2 IF B 15 DP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 998.60 4 1/2 IF B :1, --- - ~----'---------"--'-'-'--'-' .---.- BHA Weight Dry Wt 69,931 Buoyed Wt 60,131 /ncl Angle 28 Buoy+/ncl Wt 53,093 Bit Data IADC #- 115 Footage 3,215 Hrs 15.7 k Revs 123 k Grade 2-3-'NT-A-E-I-NO-TD Tool Motor Jars Bit #2 Hrs. In 82,3 110,8 27.5 Hrs. Out 108.5 126.5 43.2 26.2 BHA and Run Objective Build angle, turn direction, TO I BHA and Run Results 1~~_~I.~~~~.9.._. _..... --..-.......-.. .. ..... -. ----,_.~- ..- ._-, ..-.-.. ..--..--.. ,.-....---.... Why POOH / Comments IT~__, . .. .-.--... ...- .,,- .-..... . ... ...-."'.,--.-.. ..._~_...- .. ---...--- .~._---_.,-_.. ..-- Bit To GR=65.40', D&I=67,39',Gyro=97' ~omment I' '" Schlumberger I I II I DD's Tunnell / Robertson Co. Men Kidd / Dinger { PDM Run # 3 PDM Ser# 962-3561 I PDM Size 9 5/8 I Mud Type Sea Mud BHT F (lItem Description Bit #2 MX-C1DT TFA=1.002 I 2 95/8 XP POM 1.150 Ana *Float MONEL LC Job # 40008221 Custom-er BP .A.OW Well NS22 Field Northstar Rig Nabors 33E AFE # NSO-831326 r I II 11 II 10 I I 11 I 12 I' 13 I 14 ¡ I 15 1 ~ 16 17 3 4 5 6 7 8 9 MONEL LC MONEL STAB MWD MONEL X-OVER DH Filter Sub *fìlter* MONEL ST AS MONEL DC MONEL DC MONEL 8T AS MONEL DC HYOJARS 26 Jts, HWOP 5" Dart Valve Sub Porcupine Reamer I ! 11 I BHA and Run Objective I 'hole angle and direction BHA and Run Results Why POOH I Comments I RlS 3/4 Stages 6,0 Rev/Gal 0.113 Mud Wt 9,1 Mud Vis 15 Vendor Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana DAILEY NAD BPX STC SIN 6001306 962-3561 1 0-HA-013 10-HA-011 HA-017-SB 074 LWD S8-120 J B-15250-2 HA-002-SB NMDC-HA-023 NMDC-HA-017 HA-013-SB NMDC-HA-02C 1417-1044 26 HWDP CM7996 59834C Date In 27 -Nov-02 Time In 5:00 Depth In 3,725 TVO In 3,428 Drlg Hrs 29,2 Slide Hrs 2,5 Rot Hrs 26.7 Pump Hrs 48,5 PDM Jet Blk Bearing Mud Rubber RM 1000 Sand % ,25 Solids % 4,5 00 10 12 1/4 2x16,2x20 Jets Tool 9 5/8 8 1/8 2 13/16 8 2 13/16 8 2 7/8 8 1/4 3 1/4 8 1/2 2 13/16 8 3 1/4 8 2 7/8 8 2 7/8 7 1 5/16 2 13/16 8 2 7/8 7 15/16 2 13/16 7 3/4 3 5 3 6 3/4 3 1/8x4 1/2 7 1/2 2 3/4 BHA# Date Out 01-Dec-02 Time Out 10:00 Depth Out ì ,738 TVD Out 5.950 Drlg Ft -1-,013 Slide Ft 194 Rot Ft 3,819 Rotate % 95 Inclln 29.42 Az In 22,54 Incl Out 28,20 Az Out 24,67 Avg Dls 0,3 Max Os 1,5 RPM 100 GPM 1050 DIg TQ 14,0 WOB 40 Stab 00 F.N. Bottom Conn In lOut Top Conn 12 1/8 22.95 6 5/8 Reg P 6 5/8 Reg B 6 5/8 H90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 FH P 6 5/8 H90 8 6 5/8 H90 P 6 5/8 FH 8 6 5/8 FH P 6 5/8 H90 8 6 5/8 H-90 P 6 5/8 H-90 B 9 5/8 H-90 P 9 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H90 P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 12 1/4 2.40 1.49 12 1/4 2.40 12 1/4 2.45 1.19 12 1/4 BHA Weight Dry Wt 71,994 Buoyed Wt 62,014 Incl Angle 28 Buoy+lncl Wt 54,756 I Y_ery,_go~~.._ Drill to Colville, trip for POC, maintain ._~_,,_ __._._.___.~ ,__~__ - - _,.___.__"___._._____._..u_.____..____.__ I ~.~~~_~?}~.9.~~v~_._,________._______ ".-- ~---,,~, ..---...--.-. ,.' ._._-~--_._-_._-. ,Bit To IGR=70.15'. 0&1=72.14' Bit Data IADC # 117 Footage 4,013 Hrs 29.2 k Revs 368 k Grade 3-4-VVT-Ä-E-1/8-FC-TD Comment 3 Hole Size 12 1-+ Hole Sect Interr.-: 12.25 Bha Type Steerable Hrs BRT 101.0':) Avg ROP 137.-\.3 Slide ROP 77.6C Rot ROP 143.03 Slide % 5 Bit>Srvy _70,15 T/F Corr 328.3 Plan Ols 0,0 SPP On 3300 SPP Off 3400 Length Cum Length 1.00 1,00 30,95 31.95 9.96 41.91 9.69 51.60 5.49 57.09 27.56 84.65 1.41 86.06 2.29 88.35 5.55 93.90 30.83 124.73 30.83 155.56 5.44 161.00 30.91 191.91 30.83 222.74 780.65 1003.39 2,37 1005.76 6.39 1012,15 Tool Motor Jars Bit #2 Hrs. In 0.0 126.5 0.0 Hrs. Out 48.5 155,7 29,2 48,5 I' I "'r j,J~ Schlumberger I Job # 40008221 'I Customer 8P ADW Well NS22 I Field Northstar f Rig Nabors 33E AFE # NSD-831326 I DD's Tunnell / Robertson Co. Men Kidd / Dinger { PDM Run # 4 PDM Ser# 962-3561 I PDM Size 9 5/8 I Mud Type Sea Mud BHT F 156 , " I Descripüon Item I .1 2 "I II II I 11190 II 11 I 12 I I 14 15 II 16 I ! I ~ 3 't #3 DS69HFGLNPL TFA=1,035 95/8 XP PDM 1,15° *Float MONEL LC 4 MONEL STAB 5 COR (PWD) 6 MWD 7 MONEL X-OVER 8 DH Filter Sub *filter* MONEL STAB MONEL DC MONEL DC MONEL STAB 13 MONEL DC HYDJARS 26 Jts. HWDP 5" Dart Valve Sub BHA and Run Objective casing point. IBHA and Run Results problems in Kuparuk Why POOH I Comments R/S 3/4 Stages 6,0 Rev/Gal 0,113 Mud Wt 10.1 Mud Vis 15 Vendor Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana DAILEY NAD BPX SIN 201699 962-3561 10-HA-Ö13 HA-017-SB 8143 074 LWD SB-120 JB-15250-2 HA-002-SB NMDC-HA-023 NMDC-HA-017 HA-013-SB NMDC-HA-02C 1417-1044 26 HWDP CM7996 Date In 01-Dec-02 Time In 20:00 Depth In 7,738 TVD In 6,950 Drlg Hrs 35.8 Slide Hrs 16,3 Rot Hrs 19,5 Pump Hrs 53.0 PDM Jet Blk Bearing Mud Rubber RM 1000 Sand % ,25 Solids % 8,6 OD ID 12 1/4 9 5/8 8 1/8 8 8 7/16 8 1/4 8 1/2 8 8 8 7 15/16 8 7 15/16 7 3/4 5 6 3/4 Drill to KOP, build to 40, drill to 9 5/8 6x15 Jets Tool 2 13/16 2 7/8 3 1/4 3 1/4 2 13/16 3 1/4 2 7/8 2 7/8 2 13/16 2 7/8 2 13/16 3 3 3 1/8x4 1/2 BHA# Date Out 05-Dec-02 Time Out 8:00 Depth Out 10,743 TVD Out 9,526 Drlg Ft 3,005 Slide Ft 422 Rot Ft 2,583 Rotate % 86 Incl In 28,20 InclOut 35.92 Avg Dls 2.0 RPM 90 Dig TQ 22.0 Stab aD EN. In/ Out 12 1/8 22.95 12 1/4 2.40 15.21 1.49 12 1/4 2.40 12 1/4 2.45 BHA Weight Dry Wt 72,336 Buoyed Wt 61,207 Incl Angle 37 Buoy+lncl Wt 48,882 . ..... ... ._...___.,......._ "._0··'-'_'· .._..____.........________....,.....__ _,.._ ______.._._____ I ~_?9.~.:_~t~_~_~~_,b~~~._~~~_~,~~_~__t.?_~!~~i.r2~,___ I ~~~_9~=?__~~~.i!:~U~~i.~,t___.___ _____,,_._.',__, __, I ,Bit To \GR=64.54', Res=53,53', 0&1=83.81', PWO=55.29' Bit Data IADC # Footage 3,005 Hrs 35.8 k Revs 330 k Grade 2-2-WT-A-X-I-CT-TO 1.19 ::omment Az In 24,67 Az Out 26,03 Max Ds 2.6 GPM 925 WOB 18 Bottom Conn Top Conn 6 5/8 Reg P 6 5/8 Reg B 6 5/8 H90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 65/8 H90 P 6 5/8 FH B 65/8 FH P 6 5/8 H90 B 6 5/8 H90 P 6 5/8 FH B 6 5/8 FH P 65/8 H90 B 6 5/8 H-90 P 6 5/8 H-90 B 9 5/8 H-90 P 9 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H90 P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 Hole Size 12 1,4 Hole Sect Interm 12,25 Bha Type Steerable Hrs BRT 84.00 Avg Rap 83.94 Slide Rap 25.89 Rot Rap 132.4ô Slide % 14 Bit>Srvy 83.81 T/F Corr 78.8 Plan Dls 2,0 SPP On 3400 SPP Off 3600 Length Cum Length 1.00 1.00 30,95 31.95 9.96 41.91 5.49 47.40 22.83 70.23 27.56 97.79 1.41 99.20 2.29 101.49 5.55 107.04 30.83 137.87 30.83 168.70 5.44 174. 14 30.91 205.05 30.83 235.88 780.65 1016,53 2,37 1018,90 Tool Motor Jars Bit #2 Hrs. In 48.5 155.7 0.0 Hrs. Out 101.5 191,5 35.8 53,0 I .,'1 ,,'~ Schlumbergel' BHA# 5 l' Job # 40008221 Date In 08-Dec-02 Date Out 09-Dec-02 Hole Size 8 1/2 Customer BP ADW Time In 9:00 Time Out 21 :30 Hole Sect Interm S 1/2 Well NS22 Depth In 10,743 Depth Out 10,992 Bha Type Steerable (I Field Northstar TVD In 9,526 TVD Out 9,724 Hrs BRT 36.50 Rig Nabors 33E Drlg Hrs 10.8 Drlg Ft 249 Avg Rap 23.06 AFE # NSD-831326 Slide Hrs 0,0 Slide Ft 0 Slide Rap 0,00 I DD's Tunnell / Robertson Rot Hrs 10,8 Rot Ft 249 Rot Rap 23,06 Co, Men Polya / Dinger Pump Hrs 19,9 Rotate % 100 Slide % ° ,. I PDM Run # R/S PDM Jet Incl In 35,92 Az In 26,03 Bit>Srvy 68.69 PDM Ser# Stages Bearing Incl Out 37.59 Az Out 21.88 T/F Corr I PDM Size Rev/Gal Rubber Avg Dls 2,0 Max Ds 2,5 Plan Dls II Mud Type Inhibited KCL Mud Wt 12,8 Sand % 0.25 RPM 160 GPM 580 SPP On 3250 BHT F Mud Vis 48 Solids % 17,1 DIg TQ 19,0 WOB 20 SPP Off 3250 Item Description Vendor SIN 00 10 Stab 00 F.N. Bottom Conn Length Cum Length In lOut Top Conn I Bit #4 DS70FNPV 200976 8 1/2 4x12,2x14 1,00 1,00 TFA=.742 4 1/2 Reg P 2 6,75" Bias Unit Anadrill 60096 6 3/4 3 1/8 8 5/16 2.06 4 1/2 Reg B 3.34 4,34 Extention Sub 60276 4 1/2 IF P 3 6.75" Control Collar Anadrill 60082 6 13/16 4 7/16 4 1/2 IF B 9.84 14,18 CU-223 4 1/2 IF B 4 X-OYER Ana AFS301 6 1/2 2 3/4 4 1/2 IF P 1.35 15.53 Float Sub 4 1/2 XH B 5 NM STABILIZER Ana IMSZSS-FA 01 6 3/4 2 13/16 8 1/2 2.45 4 1/2 XH P 5.62 21.15 41/2XH B J 6 NM FLEX LC Ana 575-31-004-FLC 6 15/16 2 3/4 4 1/2 XH P 11 .40 32.55 4 1/2 XH B 7 COR (PWO) Ana 7125 6 3/4 Tool 4 1/2 XH P 22.33 54.88 , 5 1/2 FH B 8 MWO Ana 860 6 3/4 Tool 2.51 5 1/2 FH P 28.64 83.52 4 1/2 XH B 9 NM STABILIZER Ana "MSZSS-FA-OC 6 3/4 2 13/16 8 1/2 2.42 4 1/2 XH P 5.70 89.22 I Totco Ring 4 1/2 XH B 10 NM FLEX Ana 675-31-018-FC 6 3/4x 5 2 13/16 2.50 4 1/2 XH P 30.98 120.20 4 1/2 XH B 11 NM FLEX Ana MMFL-FA025 65/8x51/16 2 13/16 2.50 4 1/2 XH P 31.01 151.21 4 1/2 XH B 12 NM FLEX Ana MMFL-FA 024) 11/16x5 1/1 2 13/16 2.53 4 1/2 XH P 30.96 182.17 4 1/2 XH B 13 X-OYER Ana nXOS-FE 104: 6 3/4 2 3/4 4 1/2 XH P 1.98 1 84. 1 5 4 1/2 IF B 14 HYOJARS DAILEY 1416-1562 6 1/2 2 3/4 1.70 4 1/2 IF P 32.62 216.77 4 1/2 IF B 15 26 Jts. HWDP 5" NAD 26 HWOP 5 3 41/21FP 780.65 997.42 4 1/2 IF B 16 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 999.79 4 1/2 IF B aHA and Run Objective - ......'.....---------.,. ", -- -"._,'--,-_.._~ '-"---'--"'.".,-,--~-,.,.. - BHA Weight Dry Wt 55,180 Buoyed Wt 44,421 Inel Angle 40 Buoy+lnel Wt 34,029 Bit Data Tool Hrs. In IADC # Motor Footage 249 Jars 132.2 Hrs 10,8 Bit #2 0,0 k Revs 104 k RSS 0.0 Grade O-O-CT -C-X-I-PN-PR Comment First PO failed SHT, change control collar Hrs. Out 19,9 143,0 10.8 19.9 BHA and Run Results Why POOH / Comments I _______... _ _ .____,.._""_.__. .____"__.__.""'__._._.'"_, POOH for low Rap. Bha bent at COR, Lead Collar and Powerdrive Collar. Bit To GR=49.45', Res=XXXX', 0&1=68.69', PWO=40.20' I"·" Schlumberger II Job # 40008221 Customer BP ADW Well NS22 I Field Northstar I Rig Nabors 33E - AFE # NSD-831326 I DD's Tunnell / Robertson Co. Men Polya / Dinger ( PDM Run # PDM Ser# I PDM Size -,- Mud Type Inhibited KCL BHT F I Descripüon Item , ,I 2 ,¡ ! I I i I 1 I I 3 Bit #4 DS70FNPV TFA=.742 6,75" 8ias Unit Extention Sub 6.75" Control Collar CU-223 X-OVER Float Sub NM STA81L1ZER 4 5 6 CDR (PWD) 7 MWD 8 NM ST A81L1ZER 9 NM FLEX 10 NM FLEX 11 NM FLEX 12 Filter SUB R/S Stages Rev/Gal Mud Wt 12.8 Mud Vis 54 Vendor Anadrill Anadrill Ana Ana Ana Ana SIN Date In 10-Dec-02 Time In 2:00 Depth In 10.992 TVD In 9,724 Drlg Hrs 24.5 Slide Hrs 0,0 Rot Hrs 24,5 Pump Hrs 60,3 PDM Jet Bearing Rubber Sand % ,1 Solids % 17,1 OD ID 200976 8 1/2 4x12,2x14 00344 60286 60097 6 3/4 3 1/8 6 7/8 4 7/16 STFLS-FE-504 6 5/16 2 13/16 675-017S8 6 3/4 2 13/16 7077 6 3/4 Tool 217 6 3/4 Tool Ana MSZSS-FA-OC 6 3/4 2 13/16 Ana 675-31-018-FC 63/4x5 213/16 Ana MMFL-FA025 65/8x51/16 213/16 Ana MMFL-FA 024) 11/16x5 1/1 2 13/16 Ana DFS-FA-2001 6 7/8 3 3/16 X-OVER Ana 3TXOS-FE 104: 6 3/4 13 2 3/4 14 HYD JARS DAILEY 1416-1573 6 1/2 3 2 3/4 26 Jts, HWDP 5" NAD 26 HWDP 5 15 Dart Valve Sub BPX CM7996 6 3/4 16 BHA and Run Objective . BHA and Run Results Why POOH I Comments 3 1/8x4 1/2 BHA# Date Out 13-Dec-02 Time Out 15:00 Depth Out 12.486 TVD Out 10.845 Drlg Ft 1,494 Slide Ft 0 Rot Ft 1.494 Rotate % 100 Inclln 37,59 Az In 21.88 InclOut 40,51 Az Out 24,15 Avg Dls 1,0 Max Ds 1.4 RPM 150 GPM 550 DIg TQ 20.0 WOB 18 Stab 00 F.N. Bottom Conn In lOut Top Conn 8 5/16 2.04 8 1/2 8 1/2 2.42 2.50 2.50 2.53 1.69 BHA Weight Dry Wt 54,642 Buoyed Wt 43,988 Incl Angle 40 Buoy+lncl Wt 33,697 _, .._...____.,,____._ ~_...__,__,.., _'. ,_ __._u ...._,,_,..___"..______.._~~__._____,_. I ~~___._______.. M._. ._,.,__._______~_,. ... . _,_.~_.._.... _'''_.....__~____._" ,.__,.____.__.,~_,,_._,_.... . ._._.._..,,~,_.. "'_·'~n... _. _____,n. _.___"_ ______.__"._,,~_. Bit To GR=38.80', Res=27.60', D&I=58.07', PWD=29,55' Bit Data IADC # Footage Hrs k Revs Grade Comment 4 1/2 Reg P 4 1/2 Reg 8 4 1/2 IF P 4 1/2 IF B 4 1/2 IF B 4 1/2 IF P 4 1/2 XH 8 4 1/2 XH P 41/2XHB 4 1/2 XH P 5 1/2 FH 8 51/2 FH P 4 1/2 XH 8 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF 8 4 1/2 IF P 4 1/2 IF 8 4 1/2 IF P 4 1/2 IF 8 Tool Motor 1,494 Jars 24,5 Bit #2 221 k RSS 1-0-8T -C-X-I-ER- TO 6 Hole Size 8 1,2 Hole Sect Interm 8 1/2 Bha Type RSS Hrs BRT 85,00 Avg ROP 60,98 Slide ROP 0,00 Rot ROP 60,98 Slide % 0 Bit>Srvy 58.0ì T/F Corr Plan Dls SPP On 3150 SPP Off 3150 Length Cum Length 1,00 3.32 9.94 1.62 5.69 22.79 27.35 5.70 30.98 31.01 30.96 3.08 1.98 32.63 780.65 2,37 Hrs. In .0 10.8 10.8 1,00 4.32 14.26 15.88 21.57 44.36 71.71 77.41 108.39 139.40 170.36 173.44 175.42 208,05 988.70 991,07 Hrs. Out 60,3 24.5 35,3 71,1 I I BHA #: 1 Slide Sheet Well: NS22 Borehole: NS22 UWI/API#: 50029 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Depth In: 201,00 Inclination In: 3.33 Azimuth In: 194.66 Depth Out: 510.00 Inclination Out: 4.79 Azimuth Out: 54.23 Tot Distance: 309.00 Dist Steering: 250,00 % Steer: 80.9 Dist Rotating: 59,00 % Rot: 19.1 I Total ROP: 264.9 Steering ROP: 245.9 Rotating ROP: 393.3 Comments: Md Froml Md To I Avg ROP Rot/Slid I TF Flow SPP Off ,SPP on, WOB I RPM ITorq On ~ Svy Md I (ft) (ft) (ftlh) (RIS) n (gal/min) (psi) (psi) (10001bO (c/min) (K ftIIbs) 201.00 230,00 348.0 R 500 430 430 2.0 40 2 230,00 243.00 S M 10 510 440 440 7.0 0 0 234.50 243.00 247.00 S M 10 510 440 440 7.0 0 0 247.00 274.00 270.0 S M 10 500 450 490 15,0 0 0 263.50 274.00 304.00 360.0 S M 25 515 440 500 15.0 0 0 291,50 I 304.00 330,00 195,0 S M 25 500 430 500 20.0 0 0 320.50 330.00 360.00 300.0 S M 25 530 480 550 20.0 0 0 359.50 360,00 390.00 360,0 S M 25 510 450 520 15.0 0 0 388.50 390.00 420.00 300.0 S M50 510 450 550 20.0 0 0 1 420.00 450.00 R 510 475 550 18.0 40 3 450.00 510.00 171.4 S M60 510 475 550 15.0 0 0 ( ( ( N 822_ Bha _slide _ su rveys .xls Page 1 of 1 Directional Driller: James Tunnell Directional Driller: Alan Robertson Job #: TotalTime: 1.2 Time Steering: 1,0 Time Rotating: 0.2 % Steer: 87.1 % Rot: 12.9 Incl I Azmth I Comment n n 3.33 194.66 2,21 192,63 1.50 205.80 0.53 145.19 0.99 76.30 1.75 57.02 3/24/2003-4: 10 PM I I ( BHA #: 2 Slide Sheet Client: BP Exploration Alaska Well: NS22 Directional Driller: James Tunnell Field: Northstar Borehole: NS22 Directional Driller: Alan Robertson Structure: Northstar PF UWI/API#: 50029 Job #: Depth In: 510.00 Depth Out: 3725.00 Tot Distance: 3215.00 Total Time: 15.7 Inclination In: 6.68 Inclination Out: 29.42 Dist Steering: 1026.00 % Steer: 31.9 Time Steering: 6.0 % Steer: 38.0 Azimuth In: 45.67 Azimuth Out: 22.54 Dist Rotating: 2189.00 % Rot: 68.1 Time Rotating: 9.7 % Rot: 62,0 I Total ROP: 205.0 Steering ROP: 172.0 Rotating ROP: 225.3 Comments: 1 I Md From Md To Avg ROP Rot/Slid I TF Flow SPP Off ,SPP on, WOB I RPM ITorq On ~ Svy Md Incl Azmth Comment (ft) (ft) (ftfh) (RIS) (0) (gal/min) (psi) (psi) (10001bD (c/min) (K ftflbs) ¡O) (0) 510.00 546.00 308.6 R 650 750 850 15.0 40 4 546.00 586.00 184.6 S GO 700 950 1000 15.0 0 0 566.00 6.68 45.67 586.00 636.00 272.7 R 700 950 1000 15.0 40 3 636.00 676.00 240.0 S GO 700 950 1020 15.0 0 0 657,00 8.13 45,96 676.00 726.00 230.8 R 700 950 1000 15.0 40 4 724.00 8,98 44.44 726.00 776.00 200.0 S GO 700 1000 1100 20,0 0 0 776.00 816,00 342.9 R 700 1000 1050 20.0 40 5 816.00 876.00 276.9 S G 25 700 1000 1150 20.0 0 0 837,00 11.21 39.81 876.00 905.00 217.5 R 700 1050 1150 20.0 40 6 I 905.00 965,00 200.0 S G 20 700 1150 1200 20.0 0 0 926.00 14.01 44.20 965.00 995.00 257.1 R 700 1150 1200 20.0 40 5 995.00 1055,00 240.0 S G30 700 1150 1200 20.0 0 0 1020.00 15.60 57.84 1055.00 1089.00 408.0 R 700 1150 1200 20.0 40 5 ( 1089.00 1149.00 156.5 S GO 700 1150 1300 30.0 0 0 1113.00 17.70 54.67 1149.00 1183.00 127.5 R 700 1150 1300 30.0 40 6 1183,00 1243.00 81.8 S GO 700 1150 1300 30.0 0 0 1209.00 21.88 52.01 I 1243,00 1277,00 136.0 R 700 1150 1300 30.0 40 7 1277.00 1298.00 180.0 R 725 1240 1350 30.0 40 7 1298.00 1338.00 104.3 S GO 725 1240 1340 35.0 0 0 1302.00 23.99 50.13 1338.00 1371,00 141.4 R 725 1240 1370 30.0 40 8 1371.00 1391.00 171.4 R 715 1200 1360 35.0 40 8 1391.00 1451.00 109.1 S G -20 715 1200 1350 35.0 0 0 1397,00 25.47 49.17 1451.00 1464.00 156,0 R 715 1200 1350 35.0 40 8 1464.00 1484.00 171.4 R 715 1200 1350 35.0 40 8 1484.00 1524.00 96.0 S G -60 725 1200 1350 35.0 0 0 1488.00 27.14 44.44 1524,00 1558.00 145.7 R 725 1200 1300 30.0 40 8 1558.00 1578,00 100.0 R 730 1210 1340 30.0 40 8 1578.00 1623.00 180.0 S G -60 730 1210 1380 35.0 0 0 1583.71 27.79 39.79 1623.00 1652.00 290.0 R 720 1220 1350 30,0 40 8 1652.00 1672.00 R 900 1700 1770 15.0 40 7 1672.00 1710.00 285,0 S G -70 900 1700 1820 25.0 0 0 1676.92 28.24 35.10 1710.00 1745.00 300.0 R 900 1670 1700 10.0 40 7 1745.00 1765.00 240.0 R 910 1720 1820 20.0 40 10 1765.00 1810.00 225.0 S G -90 910 1720 1820 25.0 0 0 1767.22 27.83 31.97 1810.00 1840.00 360.0 R 910 1720 1820 20.0 40 10 1840.00 1860.00 R 890 1720 1820 10.0 40 8 1860.00 1904.00 377.1 S G -70 890 1700 1730 10.0 0 0 1861.09 28.02 26.83 1904.00 1933.00 R 890 1700 1730 5.0 40 7 1933.00 2027.00 352.5 R 900 1730 1800 20.0 40 8 1957.29 27.42 25,75 2027,00 2120,00 348.8 R 960 1820 1950 25.0 40 8 2050.94 27.40 26.64 2120.00 2180,00 257.1 S G -80 950 1820 1950 35.0 0 ° 2143.21 27.33 22.46 2180.00 2214,00 255.0 R 875 1600 1650 20.0 40 10 NS22_Bha_ slide _surveys,xls Page 1 of 2 3/24/2003-4: 10 PM 3/24/2003-4: 1 0 PM Page 2 of 2 N 822_ Bha _slide _ surveys.xls 2214.00 2309.00 407.1 R _n 1015 2000 2100 25.0 40 8 2236.70 26.84 20.79 2309.00 2402.00 279.0 R n_ 1025 2100 2150 20.0 40 9 2329.71 25.84 21.93 1 2402.00 2459.00 380.0 S G -20 900 1750 1850 25.0 0 0 2424.00 27.85 19.45 2459.00 2496.00 158.6 R n_ 1050 2150 2250 20.0 40 10 2496.00 2545.00 172.9 R n_ 1050 2150 2250 25.0 40 10 2519.45 29.11 20.04 Pump #2 down 2545.00 2590.00 270,0 R --- 1050 2150 2250 25,0 40 9 1 2590.00 2685.00 300,0 R n_ 950 1950 2000 15.0 40 8 2612,91 28,91 21.10 2685.00 2779.00 208.9 R --- 1050 1950 2000 15.0 40 8 2707.10 29.24 22.15 27ì9.00 2875.00 261.8 R n_ 1050 2200 2250 20.0 40 8 2802.04 29.37 22.85 ( 2875.00 2915,00 160.0 S G -140 970 1800 1900 25.0 0 0 2899.39 27.55 21.37 2915.00 2969.00 202.5 R n_ 970 1800 1900 25,0 40 10 2969.00 3065,00 274.3 R --- 880 1750 1850 30.0 40 10 2995,72 27.11 21.39 3065.00 3161.00 443.1 R n_ 940 1900 2050 30.0 40 10 3092.54 27.79 22.45 1 3161.00 3225.00 426.7 S G -140 1050 2250 2350 20,0 0 0 3188.01 26,16 19.60 3225.00 3256.00 R --- 1050 2250 2350 20.0 40 10 3256.00 3352,00 360.0 R --- 920 1800 1950 30.0 40 11 3283.49 24,86 16.76 3352.00 3447.00 118.7 R _n 930 1850 2050 40,0 40 11 3378,92 25.79 17.53 3447.00 3543,00 117.6 R --- 930 1850 2050 40,0 40 11 3474,58 25.69 17.76 3543.00 3594.00 113.3 R --- 860 1750 1950 40.0 40 11 3568.22 25.33 18.4 7 3594.00 3611.00 78.5 S G40 730 1500 1600 40.0 0 0 3611.00 3637.00 91.8 S G40 730 1350 1480 40.0 0 0 3637.00 3657.00 171.4 S G40 730 1350 1480 40.0 0 0 3654.29 29.42 22.54 3657.00 3725,00 226.7 R --- 730 1350 1480 35,0 40 13 I 1 I I ( BHA #: 3 Slide Sheet Client: BP Exploration Alaska Well: NS22 Directional Driller: James Tunnell Field: Northstar Borehole: NS22 Directional Driller: Alan Robertson Structure: Northstar PF UWI/API#: 50029 Job #: Depth In: 3725.00 Depth Out: 7738.00 Tot Distance: 4013.00 Total Time: 29.2 Inclination In: 29.88 Inclination Out: 28.23 Dist Steering: 194.00 % Steer: 4.8 Time Steering: 2.5 % Steer: 8.5 Azimuth In: 23.11 Azimuth Out: 24.41 Dist Rotating: 3819.00 % Rot: 95.2 Time Rotating: 26.7 % Rot: 91.5 1 Total Rap: 137.7 Steering Rap: 78.6 Rotating Rap: 143.1 Comments: 1 I Md Froml Md To I Avg ROPI Rot/Slid I TF I Flow ISPP Off ,SPP on, WOB I RPM ITorq On ~ Svy Md I Incl I Azmth I Comment (ft) (ft) (ftIh) (RlS) (0) (gal/min) (psi) (psi) (10001bD (c/min) (K ftIlbs) n n 3725.00 3742.00 204.0 R 700 1050 1080 15.0 35 10 3742.00 3745,00 36,0 R 780 1220 1300 20.0 35 10 1 3745,00 3836.00 390.0 R 700 1050 1130 18.0 60 11 3764.19 29.88 23.11 3836.00 3930.00 208.9 R 870 1500 1670 30.0 60 12 3856.16 29.92 24.69 3930,00 4024.00 181.9 R 900 1540 1740 40.0 60 12 3951.04 29.62 23.62 4024.00 4117.00 398.6 R 900 1540 1740 40,0 60 12 4043.64 29,20 23.28 4117.00 4211.00 225.6 R 760 1250 1480 35.0 90 11 4137.42 29,29 23.53 4211.00 4267.00 280.0 R 800 1375 1575 35.0 90 12 4228,61 28,76 23,74 4267.00 4305.00 253.3 R 800 1375 1575 35.0 90 12 4305.00 4399.00 433.8 R 850 1570 1620 15.0 100 11 4322.20 28.65 24.44 4399.00 4496.00 323.3 R 850 1600 1700 20.0 100 11 4416,14 29.34 23.08 4496.00 4587.00 287.4 R 850 1600 1700 20.0 100 11 4509.64 29.11 24.07 [ 4587,00 4680.00 192.4 R 860 1650 1850 15.0 95 12 4603.12 30.03 23.68 4680.00 4774.00 470.0 R 860 1650 1750 25.0 100 12 4698.87 30.99 22.58 4774.00 4868.00 235.0 R 860 1700 1900 35.0 100 13 4793.04 31.83 23.13 4868.00 4903.00 72.4 S G 150 850 1500 1650 40.0 0 0 4884.33 30,81 24.46 4903.00 4962.00 196.7 R 825 1500 1650 40.0 100 13 4962.00 4992.00 225,0 S G 180 815 1700 1800 30.0 0 0 4979.66 29.55 24.68 4992.00 5056.00 240.0 R 830 1750 1800 30.0 100 13 5056.00 5150,00 176.2 R 850 1800 1900 35.0 100 14 5072.97 29.42 23,99 5150.00 5244.00 188.0 R 850 1700 1920 35.0 100 14 5166.47 29.11 24,13 5244.00 5274.00 90,0 S G 130 830 1700 1850 40.0 0 0 5260,83 28.07 25.71 5274.00 5338.00 142.2 R 825 1700 1850 35.0 100 14 5338.00 5432.00 188,0 R 825 1700 1850 35.0 100 14 5356.72 27.88 25.88 5432.00 5526.00 170.9 R 850 1800 2000 35.0 100 14 5451.22 27,94 26.01 5526.00 5620.00 225.6 R 850 1800 1950 35.0 100 14 5542.80 28,23 26,04 5620.00 5714.00 235.0 R 860 1800 2050 35.0 100 15 5636.56 28.04 26.51 5714.00 5808.00 235.0 R 860 1850 1950 35,0 100 15 5733.46 28.17 26.44 5808.00 5901.00 139.5 R 860 1850 1950 35.0 100 15 5823.78 28.60 26.58 5901.00 5995.00 165,9 R 860 1800 1950 35.0 100 15 5918.17 28.34 26.94 5995.00 6090.00 183.9 R 860 1850 2000 35.0 100 15 6014.32 28.27 26.61 6090.00 6120.00 94.7 S G -125 860 1900 2050 25.0 0 0 6108.28 27.45 25.24 6120.00 6184.00 160.0 R 860 1900 2100 35.0 100 15 6184.00 6277.00 164.1 R 860 1950 2100 35.0 100 16 6201.39 27.50 25.47 6277.00 6371.00 92.5 R 860 1950 2050 35.0 100 15 6295.71 27.55 24.95 6371.00 6465.00 165.9 R 855 1920 2080 30.0 100 16 6388.45 27,20 25.54 6465.00 6559.00 235.0 R 855 1920 2080 30.0 100 16 6483.57 27.14 26.09 6559,00 6593.00 45.3 S G -60 860 2000 2200 30.0 0 0 6577.51 27.94 23.68 5593.00 6653.00 87.8 R 860 2000 2200 30.0 100 16 6653.00 5726.00 74.2 R 855 2000 2150 35.0 100 17 6671.87 27.98 23.92 6726.00 6747.00 157.5 R 855 2000 2150 35.0 100 17 6747.00 6841.00 80.6 R 865 2200 2350 35.0 100 17 6766.23 27.75 23.63 NS22_ Bha_slide _surveys .xls Page 1 of 2 3/24/2003-4: 10 PM 6841.00 6935.00 74.2 R 860 2275 2375 35.0 100 17 6860.53 27.87 23.92 6935.00 7029.00 117.5 R 860 2200 2250 35.0 100 17 6951.71 27.51 24.17 ( 7029,00 7122.00 80.9 R 850 2200 2300 35,0 100 17 7047.47 27.24 24.29 7122.00 7216.00 141.0 R 1050 3150 3250 40.0 80 17 7138.86 27.43 24.59 7216.00 7310.00 170.9 R 1050 3100 3200 40.0 80 17 7233.17 28.07 23.96 7310.00 7403.00 107.3 R 1050 3100 3300 40.0 80 17 7327.30 29.10 23.56 Begin adding lubricants 7403.00 7495.00 58.7 R 1050 3050 3150 40.0 100 16 7420.57 29.40 22.92 7495.00 7530.00 77.8 S G 140 1050 3300 3400 40.0 0 0 7514.50 28,62 24.20 7530.00 7590,00 50.0 R 1050 3300 3400 40.0 80 15 ( 7590,00 7685.00 62.6 R 1050 3250 3400 40.0 80 14 7608.99 28,31 24.51 1 I' jI 1 ( NS22_ Bha_ slide _ surveys.xls Page 2 of 2 3/24/2003-4: 1 0 PM BHA #: 4 Slide Sheet Client: BP Exploration Alaska Well: NS22 Directional Driller: James Tunnell Field: Northstar Borehole: NS22 Directional Driller: Alan Robertson Structure: Northstar PF UWI/API#: 50029 Job #: ( Depth In: 7738.00 Depth Out: 10743.00 Tot Distance: 3005.00 Total Time: 36.2 Inclination In: 28.54 Inclination Out: 35.92 Dist Steering: 422.00 % Steer: 14.0 Time Steering: 16.3 % Steer: 44.9 Azimuth In: 24.47 Azimuth Out: 26.03 Dist Rotating: 2583.00 % Rot: 86.0 Time Rotating: 20.0 % Rot: 55.1 I Total ROP: 83.0 Steering ROP: 26,0 Rotating ROP: 129.4 Comments: I Md Froml Md To I Avg ROPI Rot/Slid I TF I Flow ISPP Off ,sPP on, WOB I RPM ITorq On ~ Svy Md I Incl I Azmth I Comment (ft) (ft) (ft/h) (RlS) n (gal/min) (psi) (psi) (10001b0 (c/min) (K ft/lbs) (0) n 7738.00 7784.00 98.6 R 900 2300 2500 9.0 80 16 7784.00 7878.00 152.4 R 950 2650 2750 15.0 100 17 7788,95 28.54 24.47 I 7878.00 7971,00 159.4 R 1050 3150 3350 15,0 100 20 7882.71 28.55 25.09 7971.00 8065.00 216.9 R 1050 3150 3400 20.0 100 22 7976,78 28.52 25.37 8065.00 8160.00 228.0 R 1050 3100 3350 20.0 100 22 8072.65 28.43 24.87 8160,00 8254.00 115.1 R 1050 3100 3350 20.0 100 22 8166.60 28,50 25.57 8254.00 8284.00 40.0 S G -30 950 2650 2750 8.0 0 0 8260.18 28.97 25.18 8284,00 8348,00 167.0 R 950 2650 2850 20.0 100 23 8348.00 8442.00 165.9 R 1000 2800 3100 20.0 100 22 8354,60 29.09 24.95 1 8442.00 8535.00 101.5 R 1000 2850 3000 20.0 100 23 8448.13 28.91 25.11 ECO spike 17,5 pump mud away 8535.00 8547.00 102.9 R 975 2900 3050 20.0 100 23 8541.50 28,61 24.39 Pump #2 down, leaking gauge 8547.00 8629.00 182.2 R 975 2900 3050 20,0 100 24 8629.00 8723,00 161.1 R 982 2850 3100 20.0 100 24 8636.11 28.49 25.15 8723.00 8818.00 162.9 R 975 2850 3150 20.0 100 24 8730.79 28.23 24.95 8818.00 8889.00 118.3 R 975 2850 3020 12.0 100 26 8823.61 27.84 24.24 8889.00 8911.00 36.7 S GO 985 2880 3000 8.0 0 0 8911.00 8970.00 147.5 R 985 2870 3050 15.0 100 24 8917.92 27.98 24,71 8970.00 9006.00 39.3 S G -20 985 2940 3040 15.0 0 0 9006,00 9099.00 146.8 R 975 2880 3100 15.0 100 24 9012.33 28.76 24.74 9099.00 9133.00 156.9 R 985 3000 3200 17.0 100 25 9106.06 28,62 25.31 I 9133.00 9193.00 138.5 R 970 2900 3100 15.0 100 25 9193.00 9287.00 165,9 R 980 2900 3100 15.0 100 25 9199.47 28.37 24,56 9287.00 9381.00 156.7 R 980 2900 3100 15.0 100 25 9293.06 28,12 24.42 9381.00 9475.00 125.3 R 975 2950 3250 12.0 100 25 9387.35 27.94 25.36 9475,00 9569.00 112,8 R 960 3175 3275 15.0 100 24 9482,21 27.96 25.05 9569.00 9619.00 176.5 R 960 3075 3360 18,0 100 24 9574.97 27,69 25.26 9619.00 9663.00 27.5 S GO 975 3150 3200 5.0 0 0 9663.00 9698,00 175,0 R 965 3150 3300 15.0 100 22 9669,85 28,68 25.08 9698.00 9757.00 35.8 S GO 970 3150 3220 5.0 0 0 Add spike mud MW=10.0 9757.00 9792.00 190.9 R 970 3550 3750 20.0 100 23 9762.09 31.10 25,63 9792.00 9850.00 15.3 S GO 885 3000 3050 8.0 0 0 9850.00 9885.00 210.0 R 925 3200 3450 18.0 80 21 9856.82 32.57 26.29 9885.00 9944.00 30.0 S GO 945 3200 3250 6.0 0 0 9944.00 9979.00 190.9 R 940 3150 3400 18.0 100 23 9951.13 34.35 25.79 9979.00 10039.00 42.4 S GO 945 3250 3320 8.0 0 0 10039.00 10133.00 134.3 R 940 3200 3450 18.0 80 21 10045.37 36.28 26.10 10133.00 10228.00 118.7 R 940 3200 3450 18.0 100 21 10140.24 36.27 26.63 10228.00 10257.00 174.0 R 925 3250 3550 18.0 90 21 10234.33 36.42 26.19 1025ï.00 10292.00 140.0 R 925 3250 3550 18.0 90 21 ~ 0292.00 10296.00 8.3 S GO 910 3150 3200 2.0 0 0 10296.00 10322.00 97.5 R 910 3150 3350 15.0 90 21 i 0322.00 10342.00 150.0 R 910 3150 3350 15.0 90 21 10331.20 36.50 27.75 N S22_Bha _slide _surveys .xls Page 1 of 2 3/24/2003-4: 1 0 PM 3/24/2003-4:10 PM Page 2 of 2 NS22 _ Bha_ slide_surveys ,xis 1 I 1 10342.00 10380.00 20.0 S G -30 900 3050 3120 8,0 0 0 10380,00 10418.00 73.5 R n_ 930 3200 3250 18.0 90 16 Fault I 10418.00 10513.00 70.4 R --- 930 3200 3450 18.0 90 20 10427.29 37.32 28.21 10513.00 10543,00 150.0 R on 900 3150 3550 18.0 90 22 10521.88 36.87 27.62 10543.00 10555.00 10.3 S G -60 900 3150 3200 8.0 0 0 10555.00 10609.00 52.3 R n_ 925 3400 3550 18.0 90 20 10617.87 36.25 26.74 10609.00 10704.00 81.4 R --- 925 3400 3600 15.0 90 20 10656.69 35.92 26.03 10704.00 10743.00 97.5 R on 925 3400 3600 13.0 90 22 I 1 1 1 I BHA #: 5 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF I Depth In: 10743.00 Inclination In: 35.81 Azimuth In: 23,79 Depth Out: 10992.00 Inclination Out: 37.59 Azimuth Out: 21,39 Tot Distance: 249,00 Dist Steering: 0.00 Dist Rotating: 249.00 I Comments: I I Md From I Md To I Avg ROPI Rot/Slid I (ft) (ft) (ftlh) (RIS) 10743.00 10763,00 12.6 R 10763.00 10781.00 22.5 R 10781.00 10876.00 25.6 R 10876.00 10971.00 31.0 R 10971.00 10992.00 13.3 R I II I NS22 _ Bha_ slide _ surveys,xls Slide Sheet Well: NS22 Borehole: NS22 UWUAPI#: 50029 Total ROP: 23.2 Steering ROP: 0.0 TF n I RSS I Flow ISPP On BI WOB I Setting (gal/min) (psi) 1(1000 IbD 317/60% 510 2350 14,0 317/60% 600 3400 15.0 590 3200 18,0 337/60% 600 3250 20.0 580 3250 20.0 Page 1 of 1 % Steer: 0.0 % Rot: 100.0 Rotating ROP: 23,2 RPM forq On Et Svy Md I (clmin) (K ftllbs) I 120 21 130 20 160 20 10804.54 150 19 160 18 Directional Driller: James Tunnell Directional Driller: Alan Robertson Job #: Total Time: 10.8 Time Steering: 0.0 Time Rotating: 10.8 Incl I Azmth I (0) (0) 35,81 23.79 % Steer: 0.0 % Rot: 100.0 Comment 3/24/2003-4:10 PM 3/24/2003-4:10 PM Page 1 of 1 NS22_ Bha_ slide _surveys.xls I I BHA #: 6 Slide Sheet Schlurnberger Client: BP Exploration Alaska Well: NS22 Directional Driller: Field: Northstar Borehole: NS22 Directional Driller: Structure: Northstar PF UWUAPI#: 50-029-23128 Job #: ( Depth In: 10992,00 Depth Out: 12486.00 Tot Distance: 1494.00 Total Time: 24.5 Inclination In: 39.30 Inclination Out: 40.51 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 20.67 Azimuth Out: 24.15 Dist Rotating: 1494.00 % Rot: 100.0 Time Rotating: 24.5 % Rot: 100.0 I I Total Rap: 61,1 Steering Rap: 0.0 Rotating Rap: ô1.1 Comments: I RotJSlid I Duration I Md From I Md To I Course I Avg ROPI TF I RSS I Flow ISPP on, WOB I RPM rorq On ~ Svy Md I Incl I Azmth I DLS I (RIS) (hr:min) (ft) (ft) (ft) (fUh) (0) Setting (gal/min) (psi) (1000 IbO (K fUlbs) (ft) (0) (0) (°/100 ft) R 2:14 10992.00 11056,00 64.00 28.7 --- 337@60% 540 3000 20.0 150 17 10992.96 39.30 20.67 1.87 R 1:50 11056.00 11148.00 92.00 50.2 --- 540 3000 13.0 150 18 11089,05 40.29 20.02 1.12 R 1:06 11148.00 11247,00 99.00 90.0 --- 22@60% 550 3100 13.0 150 20 11186.13 41.65 20.44 1.43 I R 0:57 11247.00 11342.00 95.00 ., 1 00.0 --- 45/40% 560 3150 15.0 150 21 11281.24 42.54 21.46 1.18 R 0:50 11342.00 11438,00 96.00 115,2 -- 560 3150 18.0 150 2111377.24 42.76 22.19 0.56 R 0:53 11438.00 11567.00 129,00 146.0 --- 560 3200 18.0 150 22 11472.45 42.70 23.67 1.06 R 2:17 11567.00 11625.00 58,00 25.4 -- 570 3250 18.0 150 22 11567.30 42,21 24.92 1.03 R 2:05 11625.00 11723,00 98.00 47.0 --- 570 3250 18.0 150 22 11662.32 41.93 26.49 1.15 R 1:53 11723.00 11819,00 96,00 51.0 --- 0@20% 570 3300 12,0 150 22 11757,98 41.99 26.84 0,25 R 1:04 11819.00 11914,00 95.00 89.1 --- 570 3250 18.0 150 22 11853.08 41.64 26.80 0,37 ( R 1:21 11914.00 12010.00 96.00 71,1 -- 540 3050 18.0 150 22 11948,59 40,52 27,15 1,20 R 1:17 12010.00 12106.00 96.00 74.8 -- 340@80% 545 3050 16.0 150 19 12043.40 40.47 26.46 0.48 R 1:13 12106.00 12202,00 96.00 78,9 --- 337@40% 550 3100 16,0 150 20 12140.62 41.17 25.39 1.02 R 2:01 12202.00 12297.00 95,00 47.1 -- 555 3150 15.0 150 19 12235.59 40.74 24.79 0,61 I R 1:30 12297.00 12392.00 95.00 63.3 -- 540 3100 16.0 150 20 12330.79 40.43 24.34 0,45 R 1:56 12392.00 12486.00 94.00 48.6 0@60% 545 3150 18,0 150 20 12423.81 40.51 24.15 0.16 -- - - ~ -- ~ ,........, - ~ --- - -- - -..-¡ --=-I Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS22 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR 1" inch at DRILLING SERVICES Rig: NABORS DRLG RIG 33E inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 22184 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number in Out ftIhr % GRADE 1 1 MX-C1 6004906 16 1.031 201 510 309 0.6 215 50 4k 0 USE NEXT BHA 2 RR1 MX-C1 6004906 16 1.031 510 3725 3096 19.3 160 50 147k 35 3-2-WT -A-E-I-RG- TO 3 2 MX-C 1 OT 6001306 12.25 1.006 3725 7738 4013 29.2 129 160 619k RSS 1-0-WT -C-X-I-CT - TO 4 3 OS69HFGLNPU 201699 12.25 1.035 7738 10749 3011 28.4 24.5 160 273K RSS 1-1-WT -A-X-I-NO-PR 5 4 OS70FNPV 201573 8.5 .742 10749 12486 1737 15.5 66.3 160 149K RSS 1-0-WT-C-X~I-PJ-TO 6 5 STX-30CO 6.125 .518 12486 12886 400 15.5 26.3 80 - - - --"'I - ~ - -- - -- - ~ - - Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS22 13.375" inch at 3706 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 10680 ft Lease: NORTHST AR 7" inch at 12469 ft DRILLING SERVICES Rig: NABORS DRILLING RIG 33E 4.5" inch at ft Mud Company: BAROID DRILLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22184 - - Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf f Mf Chlorides Calcium Comments Date ft Ib/gal see LBf100 10Sf10M mlf30 ml@deg F 32's % % % % mgelhg ppm ppm 11/:¿1/U:¿ U4 IUS 1J6 :¿4 51 1 1S/:¿1/:¿:¿ 19.U :¿ J.:¿ U.U 96.1S .:¿~ :¿.U 1S.5 U.UU U.U5/U.;W 1I5UU ISUU \mlll n 9 11/:¿:íUU:¿ 1557 9.U 91 19 45 :¿1/:¿IS/J1 1U.5 :¿ 4.6 95.:¿ :¿ 5.U 6.5 O.UU U.UlU.:¿5 175UU IISU \Jrllllng 11/:¿J/U:¿ J/:¿~ 9.:¿ 57 15 J5 16/:¿J/:¿5 IS.:¿ :¿ 6.U 1.0 93.U :¿ 5.U 6.6 U.1U U.U~/U.4O 16UUU (ISU ....UUH 11/:¿4/U:¿ 37:¿5 \,m ISlana 11/:¿5/U:¿ 3n5 'Un Islana 11/:¿6/U:¿ 3/:¿5 'UTf ISlana 11/:¿7/U:¿ 3n5 6.6 11 13 :¿1 15.0 1 1.6 O.U 91S.:¿ U U.U 9.3 U.15 U.1U/U.:¿U 160UU 15U 'Walt Tor {;~l:i 11/:¿1S/0:¿ 39U4 1S.6 56 15 19 5/7/1S 11.:¿ 1 1.1S U.U 91S.:¿ 0 U.U 6.1 U.1U U.U5/U.:¿U 16UUU 6:¿U \Jrlllmg 11/:¿9/U:¿ 656U 9.U 47 13 :¿3 1S/1U/13 6.U 1 4.3 U.5 95.:¿ U.:¿5 :¿.5 8.9 U.:¿O U.1U/U.4O 16:¿UU 6:¿U \Jrllllng 11/3U/U:¿ {(36 9.1 5U 15 U 6/11/14 5.6 1 5.5 U.5 94.U U.:¿5 6.U 6.7 U.1U U.U5/U.JU 16UUU 6UU \:sIt I rip 1:íUU1/U:¿ 7736 9.1 5:¿ 13 :¿1 6/11/13 5.U 1 5.5 1.5 93.U U.:¿5 6.U 1S.5 U.1U U.U5/U.3U 16UUU ISUU \:sIt I rip 1 :íUU:íUU:¿ 1S97U 9.:¿ ~1 15 :¿:¿ 1S/1 U/1:¿ 1.6 :¿ 5.4 1.0 9:¿.6 U.:¿5 I.U 6.U U.UU U.UUlU.J5 16UUU Ö:¿U 'Urllllng 1 :íUU3/U:¿ 101:¿9 1U.1 4ö 15 :¿7 1 :íU11S/:¿3 4.:¿ 1U.4 1 9.5 :¿.U 1S1S.5 0.:¿5 6.5 1S.5 U.1U U.U5/U. (5 16UUU ISUU \Jrllllng . 1 :íUU4/U:¿ 1U(43 1U.:¿ 4:¿ 13 :¿5 1U/15/11S 5.:¿ 11.:¿ 1 9.9 1.5 6ö.6 U.:¿5 1S.5 9.U U.:¿U U.1U/U.75 16UUU öUU I rip Tor 9 5/6" 1:íUU5/U:¿ 1U/43 1U.:¿ 44 11 :¿3 fl1:íU15 5.:¿ 11.:¿ :¿ 9.9 1.5 61S.6 U.:¿5 1S.5 6.U U.UU U.UUIU.75 11SUUU 6UU 'kun 9 5/ö" {;~l:i 1 :íUU6/U:¿ 1U/43 1U.1 41 1:¿ :¿1 7/11/11 5.:¿ 11.4 :¿ 9.5 1.5 1S9.U 0.:¿5 9.U IS.U U.UU U.UU/U.75 16UUU ISUU \;M I 9 5/6" 1 :íUU7/U:¿ 1U743 1U.1 41 1:¿ :¿1 7/11/16 5.:¿ 11.4 :¿ 9.5 1.5 69.U U.:¿5 9.U 6.U U.UU U.UU/U.75 16UUO 6UO klg Kepalr 1 :íUU6/U:¿ 1U/43 1 :¿.6 5U :¿~ :¿4 1 U/34I56 5.:¿ 1U.4 :¿ :¿U.5 3.U 76.5 U.:¿5 I.U 1U.U U.6U U.36/U.9U 4ISUUU 1S6U \Jrlll uut {;~l:i · 1:íUU9/U:¿ 1U99:¿ 1 :¿.6 4IS :¿3 :¿4 9/41/56 5.6 11.6 :¿ :¿U.5 3.U 76.5 U.:¿5 I.U 6.3 U.1U U.U5/:¿.3U 5UUOU ölSU I ripping 1:íU1U/U:¿ 11116 1 :¿.6 54 :¿9 31 1 U/54I 19 5.U 11.U :¿ :¿U.5 3.U 76.5 .:¿5 7.:¿ 6.6 U.3U U.1U/:¿.4O 540UU 1S6U \Jrllllng 1:íU11/U:¿ 1:íl!4UU 1 :¿.6 54 :¿IS 34 14/64/66 4.4 9.1S :¿ :¿U.5 3.U 16.5 .1U 1.5 6.3 U.:¿U U.U5/:¿.ISU 5UUUU ÖUU \Jrllllng 1:íU1:íUU:¿ 1 :¿41S6 13.3 5U 3:¿ 37 1 J/4ö/65 3.1S 6.4 :¿ :¿:¿. I 1.5 (5.ö U 6.6 6.6 U.U5 U.1U/:¿.1U 51UUU ISUU ~lrcUlatlng U1/16/U3 1:¿4IS6 9.1 4:» 15 :¿6 6/1U/11 5.4 1 5.4 U.U 94.6 U U.U 9.5 U.1U U.U5/U.3U 16UUO 640 ~Ov,"g f<lg U1/17/U3 1:¿4IS6 9.1 4ö 15 :¿5 9/11/U 5.3 U 5.4 U.U 94.6 U U.U 9.J U.1U U.U5/U.3U 16UUU 64U \JlsplBce Ulesel U1/16/U3 1:¿41S6 9.1 4:¿ 14 :¿1 6/1U/11 6.U 1 5.5 U.7 93.ö U U.U lS.b U.UU U.U5/U.:¿5 11SUUU 1S4O klH U1/19/U3 1:¿ö66 9.3 44 11 :¿:¿ 10/13/14 5.U 1 1.9 U.1 9:¿.U U U.1 6.1S U.1U U.U6/1.3U 16UUU IS4U '\.oUUH . - ~-----~..-....---.------ ~ Final Survey NS22.TXT ANADRILL SCHLUMBERGER survey report client.. .................: BP Exploration (Alaska) Inc. Fi e 1 d. . . . . . . . . . . . . . . . . . . .: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS22 API number.... ...... .....: 50-029-23128-00 Engineer.................: M. Aburto RIG:.....................: Nabors 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. .........: Mean Sea Level Depth reference..........: Driller's pipe Tally GL above permanent.......: 15.90 ft KB above permanent. ......: na OF above permanent.......: 56.51 ft ----- vertical section origin---------------- Latitude C+N/S-).........: 0.00 ft Departure C+E/W-)........: 0.00 ft ----- platform reference point--------------- Latitude C+N/S-).........: -999.25 ft Departure C+E/W-)........: -999.25 ft Azimuth from rotary table to target: 25.75 degrees [(c)2003 Anadrill IDEAL ID6_1C_10Jo ANADRILL SCHLUMBERGER Survey Report of 6 19-Jan-2003 22:33:07 page 1 of 6 spud date... ..... ........: 21-Nov-2002 Last survey date. ..... ...: 19-Jan-03 Total accepted surveys...: 144 MD of first survey.... ...: 0.00 ft MD of last survey........: 12887.00 ft oi spl oi sp 1 Tota 1 Geomagnetic data ---------------------- Magnetic model......... ..: BGGM version 2001 Magnetic date...... ......: 30-NOv-2002 Magnetic field strength..: 1150.50 HCNT Magneti c dec (+E/W-).....: 26.26 degrees Magnetic dip..... ........: 80.94 degrees ----- MWD survey Reference Reference G...... ........: Reference H..............: Reference Dip.... ........: Tolerance of G......... ..: Tolerance of H...........: Tolerance of Dip.........: criteria --------- 1002.69 mGal 1151.00 HCNT 80.95 degrees C+/-) 2.50 mGal C+/-) 6.00 HCNT C+/-) 0.45 degrees ----- corrections --------------------------- Ma~netic dec C+E/W-).. ...: 26.09 degrees Grld convergence C+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.09 degrees (Total az corr = magnetic dec - grid con v) sag applied (V/N). .......: No degree: 0.00 19-Jan-2003 22:33:07 page 2 seq Measured TOO-' TVO vertical -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- Srvy ------ ------ Incl Azimuth course page 1 At DLS # depth qual (ft) type - ------_---..._"-~- angle angle length (deg) (deg) eft) Final Survey Ns22.TXT depth section +N/S- eft) eft) eft) ;-~ +E/W- displ Azim (deg/ tool eft) (ft) (deg) 100f) type ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- 0.00 0.00 ------ 6 7 8 9 10 11 12 13 14 15 16 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 0.00 0.00 0.00 0.00 50.00 99.99 149.95 199.88 234.32 263.29 291.28 320.27 359.27 388.26 472.11 565.14 655.38 721.64 832.88 17 926.00 14.01 44.20 89.00 919.73 18 1020.00 15.60 57.84 94.00 1010.63 19 1113.00 17.70 54.67 93.00 1099.73 20 1209.00 21.88 52.01 96.00 1190.04 234.50 263.50 291.50 320.50 359.50 388.50 472.50 566.00 657.00 724.00 0.76 184.47 50.00 1.58 187.68 50.00 2.69 187.88 50.00 3.35 185.25 50.00 3.33 194.66 34.50 2.21 192.63 29.00 1.50 205.80 28.00 0.53 145.19 29.00 0.99 76.30 39.00 1.75 57.02 29.00 4.79 54.23 84.00 6.68 45.67 93.50 8.13 45.96 91.00 8.98 44.44 67.00 837.00 11.21 39.81 113.00 0.00 0.00 -0.31 -0.33 -1.27 -1.34 -3.05 -3.19 -5.53 -5.81 -7.46 -7.78 -8.83 -9.14 -9.72 -10.00 -10.17 -10.45 -10.04 -10.52 -9.50 -10.22 -5.32 -7.47 3.22 14.24 23.64 42.65 61.26 82.77 105.74 134.57 page 2 -1.39 6.79 13.81 28.55 0.00 -0.03 -0.14 -0.40 -0.69 -1.04 -1.37 -1.65 -1.74 -1.31 -0.69 3.23 10.29 18.70 25.77 38.98 0.00 0.33 184.47 1.52 1.35 186.11 1.64 3.21 187.09 2.22 5.85 186.79 1.35 7.85 187.59 1.59 9.24 188.54 3.88 10.13 189.37 2.94 10.59 189.45 4.56 10.60 187.09 2.41 10.24 183.88 3.03 8.14 156.62 3.62 10.38 97.67 2.21 19.89 70.05 1.59 29.24 61.80 1.31 48.31 53.78 2.10 42.92 52.03 67.45 50.48 3.32 57.81 70.67 91.30 50.71 4.06 72.65 92.79 117.84 51.94 2.46 92.10 118.81 150.33 52.22 4.45 TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR ""'"-- ---------- - -. Fi na 1 Survey NS22.TXT 21 1302.00 23.99 50.13 93.00 1275.69 167.34 114.89 146.98 186.55 51.98 2.40 GYR 22 1397.00 25.47 49.17 95.00 1361.97 203.67 140.63 177.26 226.27 51.57 1.61 GYR 23 1488.00 27.14 44.44 91.00 1443.55 241.30 168.25 206.60 266.44 50.84 2.94 GYR 24 1583.71 27.79 39.79 95.71 1528.49 283.63 200.98 236.17 310.11 49.60 2.34 MWD_IFR 25 1676.92 28.24 35.10 93.21 1610.78 326.47 235.72 262.76 353.00 48.10 2.41 MWD_IFR 26 1767.22 27 . 83, 31.97 90.30 1690.49 368.51 271.09 286.20 394.21 46.55 1.69 MWD_IFR 27 1861.09 28.02 26.83 93.87 1773.44 412.34 309.36 307.76 436.37 44.85 2.57 MWD_IFR 28 1957.29 27.42 25.75 96.20 1858.60 457.08 349.47 327.58 479.00 43.15 0.81 MWD_IFR 29 2050.94 27.40 26.64 93.65 1941.74 500.19 388.15 346.61 520.39 41.76 0.44 MWD_I FR . 30 2143.21 27.33 22.46 92.27 2023.69 542.57 426.71 364.22 561.02 40.48 2.08 MWD_IFR [(c)2003 Anadrill IDEAL ID6_1C_I0]O ANADRILL SCHLUMBERGER Survey Report of 6 19-Jan-2003 22:33:07 page 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ seq Measured Incl Azimuth Course Tool # depth angle angle length qual (ft) (deg) (deg) eft) TVO vertical oi s p 1 +N/S- eft) oispl Total +E/W- di sp 1 eft) (ft) At DLS Srvy Azim (deg/ tool (deg) 100f) type depth section eft) eft) type -------- ------ ------- ------ -------- -------- ---------------- --------------- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ 31 2236.70 26.84 20.79 93.49 2106.93 MWD_IFR 32 2329.71 25.84 21.93 93.01 2190.28 MWD_IFR 33 2424.00 27.85 19.45 94.29 2274.41 MWD_IFR 34 2519.45 29.11 20.04 95.45 2358.31 585.03 466.28 379.91 601.46 39.17 0.97 626.17 504.71 394.94 640.87 38.04 1.20 668.57 544.54 409.95 681.61 36.97 2.44 713.83 587.38 425.33 725.20 35.91 1.35 page 3 ------- - ---- --. ~ -.. F; na 1 survey Ns22.TXT MWD_IFR 35 2612.91 28.91 21.10 93.46 2440.04 758.97 629.81 441.25 769.01 35.02 0.59 MWD_IFR 36 2707.10 29.24 22.15 94.19 2522.36 804.62 672.36 458.12 813.60 34.27 0.65 MWD_IFR 37 2802.04 29.37 22.85 94.94 2605.15 851.02 715.29 475.91 859.15 33.64 0.39 MWD_IFR 38 2899.39 27.55 21.37 97.35 2690.74 897.31 758.26 493.38 904.65 33.05 2.00 MWD_IFR 39 2995.72 27.11 21.39 96.33 2776.31 941.41 799.45 509.50 948.00 32.51 0.46 MWD_IFR 40 3092.54 27.79 22.45 96.82 2862.23 985.94 840.85 526.17 991.91 32.04 0.86 MWD_IFR 41 3188.01 26.16 19.60 95.47 2947.32 1029.09 881.25 541.73 1034.44 31.58 2.18 MWD_IFR 42 3283.49 24.86 16.76 95.48 3033.49 1069.84 920.29 554.58 1074.48 31.07 1.87 MWD_IFR 43 3378.92 25.79 17.53 95.43 3119.75 1110.20 959.30 566.62 1114.14 30.57 1.03 MWD_IFR 44 3474.58 25 . 69 17.76 95.66 3205.92 1151.33 998.89 579.21 1154.67 30.11 0.15 MWD_IFR 45 3568.22 25.33 18.47 93.64 3290.43 1191.30 1037.22 591.74 1194.14 29.71 0.50 MWD_IFR 46 3654.29 29.42 22.54 86.07 3366.85 1230.69 1074.22 605.69 1233.21 29.42 5.22 MWD_IFR 47 3764.19 29.88 23.11 109.90 3462.36 1284.99 1124.33 626.78 1287.24 29.14 0.49 MWD_IFR 48 3856.16 29.92 24.69 91.97 3542.09 1330.80 1166.24 645.35 1332.89 28.96 0.86 MWD_IFR 49 3951.04 29.62 23.62 94.88 3624.45 1377.89 1209.23 664.63 1379.84 28.79 0.64 MWD_IFR 50 4043.64 29.20 23.28 92.60 3705.11 1423.33 1250.94 682.73 1425.12 28.62 0.49 MWD_IFR 51 4137.42 29.29 23.53 93.78 3786.94 1469.11 1292.99 700.93 1470.75 28.46 0.16 MWD_IFR 52 4228.61 28.76 23.74 91.19 3866.68 1513.32 1333.52 718.66 1514.84 28.32 0.59 MWD_IFR 53 4322.20 28.65 24.44 93.59 3948.77 1558.25 1374.56 737.01 1559.68 28.20 0.38 MWD_IFR 54 4416.14 29.34 23.08 93.94 4030.93 1603.76 1416.23 755.35 1605.08 28.07 1.02 MWD_IFR 55 4509.64 29.11 24.07 93.50 4112.53 1649.37 1458.07 773.61 1650.59 27.95 0.57 MWD_IFR page 4 ---~......-_------ F; na 1 Survey NS22.TXT 56 4603.12 30.03 23.68 93.48 4193.84 1695.48 1500.26 792.28 1696.61 27.84 1.01 MWD_IFR 57 4698.87 30.99 22.58 95.75 4276.33 1744.04 1544.96 811.36 1745.05 27.71 1.16 MWD_IFR 58 4793.04 31.83 23.13 94.17 4356.70 1793.05 1590.18 830.43 1793.96 27.57 0.94 MWD_IFR 59 4884.33 30.81 24.46 91.29 4434.68 1840.47 1633.60 849.57 1841.31 27.48 1.35 MWD_IFR 60 4979.66 29.55 24.68 95.33 4517.09 1888.39 1677.19 869.49 1889.17 27.40 1.33 MWD_IFR [(c)2003 Anadrill IDEAL ID6_1C_10]O ANADRILL SCHLUMBERGER survey Report 19-Jan-2003 22:33:07 page 4 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ Seq Measured Incl Azimuth Course TVD vertical D; sp 1 Di sp 1 Tota 1 At DLS srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degj tool qual eft) (deg) edeg) eft) eft) eft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ 61 5072.97 29.42 23.99 93.31 4598.32 1934.30 1719.03 888.42 1935.03 27.33 0.39 MWD_IFR 62 5166.47 29.11 24.13 93.50 4679.88 1979.99 1760.77 907.05 1980.67 27.26 0.34 MWD_IFR 63 5260.83 28.07 25.71 94.36 4762.74 2025.13 1801.72 926.07 2025.78 27.20 1.36 MWD_IFR 64 5356.72 27.88 25.88 95.89 4847.42 2070.11 1842.22 945.64 2070.75 27.17 0.21 MWD_IFR 65 5451.22 27.94 26.01 94. 50 4930.93 2114.35 1881.99 964.99 2114.97 27.15 0.09 MWD_IFR 66 5542.80 28.23 26.04 91. 58 5011.73 2157.46 1920.74 983.91 2158.08 27.12 0.32 MWD_IFR 67 5636.56 28.04 26.51 93.76 5094.41 2201.67 1960.38 1003.48 2202.29 27.11 0.31 MWD_IFR 68 5733.46 28.17 26.44 96.90 5179.88 2247.31 2001.24 1023.83 2247.93 27.09 0.14 MWD_IFR 69 5823.78 28.60 26.58 90.32 5259.34 2290.25 2039.67 1043.00 2290.87 27.08 0.48 MWD_IFR 70 5918.17 28.34 26.94 94.39 5342.32 2335.24 2079.84 1063.25 2335.86 27.08 0.33 page 5 ---..-- - -- - Fi na 1 Survey Ns22.TXT MWD_IFR 71 6014.32 28.27 26.61 96.15 5426.97 2380.82 2120.54 1083.79 2381.45 27.07 0.18 MWD_IFR 72 6108.28 27.45 25.24 93.96 5510.04 2424.73 2160.03 1102.99 2425.35 27.05 1.11 MWD_IFR 73 6201.39 27.50 25.47 93.11 5592.65 2467.68 2198.85 1121.39 2468.29 27.02 0.13 MWD_IFR 74 6295.71 27.55 24.95 94.32 5676.29 2511.27 2238.28 1139.96 2511.86 26.99 0.26 MWD_IFR 75 6388.45 27.20 25.54 92.74 5758.65 2553.91 2276.86 1158.14 2554.48 26.96 0.48 MWD_IFR 76 6483.57 27.14 26.09 95.12 5843.27 2597.34 2315.96 1177.06 2597.90 26.94 0.27 MWD_IFR 77 6577.51 27.94 23.68 93.94 5926.57 2640.76 2355.35 1195.32 2641.30 26.91 1.46 MWD_IFR 78 6671.87 27.98 23.92 94.36 6009.92 2684.98 2395.83 1213.17 2685.48 26.86 0.13 MWD_IFR 79 6766.23 27.75 23.63 94.36 6093.33 2729.06 2436.19 1230.95 2729.52 26.81 0.28 MWD_IFR 80 6860.53 27.87 23.92 94.30 6176.74 2773.02 2476.45 1248.69 2773.45 26.76 0.19 MWD_IFR 81 6951.71 27.51 24.17 91.18 6257.48 2815.38 2515.15 1265.95 2815.78 26.72 0.41 MWD_IFR 82 7047.47 27.24 24.29 95.76 6342.52 2859.39 2555.30 1284.02 2859.77 26.68 0.29 MWD_IFR 83 7138.86 27.43 24. 59 91.39 6423.70 2901.35 2593.51 1301.38 2901.70 26.65 0.26 MWD_IFR 84 7233.17 28.07 23.96 94.31 6507.16 2945.24 2633.54 1319.44 2945.58 26.61 0.75 MWD_IFR 85 7327.30 29.10 23.56 94.13 6589.82 2990.25 2674.76 1337.58 2990.56 26.57 1.11 MWD_IFR 86 7420.57 29.40 22.92 93.27 6671.20 3035.78 2716.63 1355.56 3036.05 26.52 0.46 MWD_IFR 87 7514.50 28.62 24.20 93.93 6753.34 3081.30 2758.39 1373.76 3081. 54 26.47 1.06 MWD_IFR 88 7608.99 28.31 24.51 94.49 6836.41 3126.32 2799.42 1392.33 3126.55 26.44 0.36 MWD_IFR 89 7697.26 28.23 24.41 88.27 6914.15 3168.12 2837.47 1409.64 3168.33 26.42 0.11 MWD_IFR 90 7788.95 28.54 24.47 91.69 6994.82 3211.69 2877.15 1427.68 3211.90 26.39 0.34 MWD_IFR page 6 - - --- - - -- Final Survey NS22.TXT [(c)2003 Anadrill IDEAL ID6_1C_10]O ANADRILL SCHLUMBERGER survey Report of 6 19-Jan-2003 22:33:07 page 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ Seq Measured Incl Azimuth Course Tool # depth angle angle length qual (ft) (deg) (deg) (ft) TVO vertical Di s p 1 +NjS- eft) oispl Total +E/W- displ eft) (ft) At DLS srvy Azim (deg/ tool (deg) 100f) type depth section (ft) eft) type -------- ------ ------- ------ -------- -------- ---------------- --------------- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ ------ 91 7882.71 28.55 25.09 93.76 7077.18 3256.49 2917.83 1446.46 3256.68 26.37 0.32 MWD_IFR 92 7976.78 28.52 25.37 94.07 7159.82 3301.43 2958.48 1465.61 3301.61 26.35 0.15 MWD_IFR 93 8072.65 28.43 24.87 95.87 7244.10 3347.13 2999.87 1485.01 3347.31 26.34 0.27 . MWD_IFR 94 8166.60 28.50 25.57 93.95 7326.69 3391.91 3040.37 1504.09 3392.08 26.32 0.36 MWD_IFR 95 8260.18 28.97 25.18 93.58 7408.74 3436.89 3081.02 1523.37 3437.06 26.31 0.54 MWD_IFR 96 8354.60 29.09 24.95 94.42 7491.30 3482.71 3122.53 1542.78 3482.87 26.29 0.17 MWD_IFR 97 8448.13 28.91 25.11 93.53 7573.10 3528.05 3163.61 1561.97 3528.20 26.28 0.21 MWD_IFR 98 8541.50 28.61 24.39 93.37 7654.96 3572.97 3204.41 1580.78 3573.11 26.26 0.49 MWD_IFR 99 8636.11 28.49 25.15 94.61 7738.06 3618.18 3245.47 1599.72 3618.31 26.24 0.40 MWD_IFR 100 8730.79 28.23 24.95 94.-68 7821.38 3663.15 3286.21 1618.76 3663.27 26.22 0.29 MWD_IFR 101 8823.61 27.84 24.24 92.82 7903.31 3706.76 3325.88 1636.92 3706.88 26.21 0.55 MWD_IFR 102 8917.92 27.98 24.71 94.31 7986.65 3750.90 3366.05 1655.21 3751.01 26.19 0.28 MWD_IFR 103 9012.33 28.76 24.74 94.41 8069.72 3795.75 3406.80 1673.97 3795.85 26.17 0.83 MWD_IFR 104 9106.06 28.62 25.31 93.73 8151.94 3840.74 3447.57 1693.01 3840.84 26.15 0.33 MWD_IFR 105 9199.47 28.37 24.56 93.41 8234.04 3885.30 3487.98 1711.80 3885.39 26.14 0.47 MWD_IFR page 7 - -, - - - -- -~~; Fi na 1 survey NS22.TXT 106 9293.06 28.12 24.42 93.59 8316.48 3929.58 3528.29 1730.16 3929.66 26.12 0.28 MWD_IFR 107 9387.35 27.94 25.36 94.29 8399.71 3973.89 3568.48 1748.80 3973.96 26.11 0.51 MWD_IFR 108 9482.21 27.96 25.05 94.86 8483.51 4018.34 3608.71 1767.74 4018.42 26.10 0.15 MWD_IFR 109 9574.97 27.69 25.26 92.76 8565.54 4061.64 3647.90 1786.14 4061.71 26.09 0.31 MWD_IFR 110 9669.85 28.68 25.08 94.88 8649.17 4106.45 3688.46 1805.20 4106.52 26.08 1.05 MWD_IFR 111 9762.09 31.10 25.63 92.24 8729.14 4152.41 3729.99 1824.89 4152.48 26.07 2.64 MWD_IFR 112 9856.82 32.57 26.29 94.73 8809.62 4202.38 3774.91 1846.77 4202.44 26.07 1.59 MWD_IFR 113 9951.13 34.35 25.79 94 . 31 8888.29 4254.37 3821.63 1869.59 4254.44 26.07 1.91 MWD_IFR 114 10045.37 36.28 26.10 94.24 8965.19 4308.85 3870.62 1893.43 4308.91 26.07 2.06 MWD_IFR 115 10140.24 36.27 26.63 94.87 9041.67 4364.97 3920.91 1918.35 4365.04 26.07 0.33 MWD_IFR 116 10234.33 36.42 26.19 94.09 9117.46 4420.73 3970.85 1943.16 4420.80 26.08 0.32 MWD_IFR 117 10331.20 36.51 26.99 96.87 9195.36 4478.30 4022.33 1968.92 4478.37 26.08 0.50 MWD_IFR 118 10427.29 37.34 28.14 96.09 9272.18 4535.99 4073. 50 1995.64 4536.08 26.10 1.12 MWD_IFR 119 10521.88 36.89 26.78 94.59 9347.61 4593.04 4124.14 2021.96 4593.14 26.12 0.99 MWD_IFR 120 10617.87 36.25 26.19 95.99 9424.70 4650.23 4175.33 2047.47 4650.33 26.12 0.76 MWD_IFR [(c)2003 Anadrill IDEAL 1D6_1C_10JO ANADRILL SCHLUMBERGER survey Report of 6 19-Jan-2003 22:33:07 page 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ seq Measured 1ncl Azimuth Course TVD vertical Di sp 1 Di sp 1 Tota 1 At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual eft) (deg) (deg) (ft) (ft) eft) (ft) (ft) (ft) (deg) 100f) type type page 8 -.-.-- - - -- Fi na 1 survey Ns22.TXT --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ 121 10656.69 35.92 25.93 38.82 9456.07 4673.09 4195.87 2057.52 4673.19 26.12 0.94 MWD_IFR 122 10804.54 35.81 23.79 147.85 9575.90 4759.69 4274.46 2093.93 4759.78 26.10 0.85 MWD_IFR 123 10898.24 37.59 21.39 93.70 9651.02 4815. 59 4326.16 2115.41 4815.66 26.06 2.44 MWD_IFR -:- 124 10992.96 39.30 20.67 94.72 9725.21 4874.28 4381.13 2136. 54 4874.33 26.00 1.87 MWD_IFR 125 11089.05 40.29 20.02 96.09 9799.03 4935.51 4438.79 2157.92 4935.53 25.93 1.12 MWD_IFR 126 11186.13 41.65 20.44 97.08 9872.33 4998.86 4498.51 2179.93 4998.87 25.85 1.43 MWD_IFR 127 11281.24 42.54 21.46 95.11 9942.91 5062.40 4558.05 2202.73 5062.40 25.79 1.18 MWD_IFR 128 11377.24 42.76 22.19 96.00 10013.52 5127.28 4618.43 2226.91 5127.28 25.74 0.56 MWD_IFR 129 11472.45 42.70 23.67 95.21 10083.46 5191.81 4677.93 2252.08 5191.81 25.71 1.06 MWD_IFR 130 11567.30 42.21 24.92 94.85 10153.44 5255.81 4736.28 2278.42 5255.81 25.69 1.03 MWD_IFR 131 11662.32 41.93 26.49 95.02 10223.98 5319.47 4793.64 2306.03 5319.47 25.69 1.15 MWD_IFR 132 11757.98 41.99 26.84 95.66 10295.11 5383.42 4850.80 2334.73 5383.42 25.70 0.25 MWD_IFR 133 11853.08 41.64 26.80 95.10 10365.99 5446.82 4907.39 2363.34 5446.82 25.71 0.37 MWD_IFR 134 11948.59 40.52 27.15 95.51 10437.98 5509.56 4963.32 2391.81 5509.56 25.73 1.20 MWD_IFR 135 12043.40 40.47 26.46 94.81 10510.08 5571.12 5018.27 2419.57 5571.12 25.74 0.48 MWD_IFR 136 12140.62 41.17 25.39 97.22 10583.66 5634.67 5075.43 2447.35 5634.67 25.74 1.02 MWD_IFR 137 12235.59 40.74 24.79 94.97 10655.38 5696.91 5131.80 2473.75 5696.91 25.74 0.61 MWD_IFR 138 12330.79 40.43 24.34 95.20 10727.68 5758.83 5188.13 2499.50 5758.83 25.72 0.45 MWD_IFR 139 12423.81 40 . 51 24.15 93.02 10798.44 5819.19 5243.18 2524.29 5819.19 25.71 0.16 MWD_IFR 140 12563.65 41.20 24.48 139.84 10904.21 5910.63 5326.54 2561.95 5910.64 25.69 0.52 D-MAG 141 12659.05 40.98 24.59 95.40 10976.11 5973.32 5383.58 2587.99 5973.32 25.67 0.24 D-MAG page 9 - """- - ~ - -. - Final survey Ns22.TXT 142 12754.43 40.04 22.55 95.38 11048.63 6035.22 5440.35 2612.77 6035.23 25.65 1.70 D-MAG 143 12790.42 40.55 20.94 35.99 11076.08 6058.44 5461.97 2621.39 6058.45 25.64 3.22 D-MAG projected to TD 144 12887.00 40.55 20.94 96.58 11149.47 6121.01 5520.61 2643.83 6121.03 25.59 0.00 PRO] [(c)2003 Anadrill IDEAL ID6_1C_10] page 10 - - ~- - NS22 - Spud 11/21/2002 Prognosed Tops Actual Depths Formation TVDss I TVDrkb I MDrkb TVDss I TVDrkb I MDrkb Top Permafrost 1.149 1206 1218 1149 1206 1218 Base Permafrost 1.S i 9 ]576 1613 1519 1576 1613 SV6 - top confming zone 3.0]5 ^'n"ì 3317 3034 3091 3347 .JV/,-, SV5 - base confining zone 3287 334::l 3627,52 3311 3368 3655 Surface casing point 3,350 3407 3699 3371 3428 3725 Well suspended at this point to bring out 95/8" casing SV4 3.597 3654 3982 3615 3672 4006 SV2 - top upper injection zone 3.997 4054 i'-' .--'"'"1 4023 4080 4280 'f.J).:> SVl - top major shale barrier 4.412 4469 4912 4426 4483 4941 TMBK - top lower injection zone - Top Ugnu 4,793 4850 5347 4782 4839 5347 WS1- top Schrader Bluff - Base Ugnu 6.398 6455 7180 6375 6432 7148 CM3 - Base lower injection zone (top Colville) 6.887 6944 7739 6947 7004 7799 THRZ - Top HRZ 8.777 8834 9897 8738 8795 9842 BHRZ - Base HRZ 8~83 7 8894 9966 8813 8870 9933 Top Kuparuk 8.897 8954 ]0037 8928 8985 10065 Kuparuk C 9. ]0] 9158 10286 9133 9190 10326 Unnamed fault - 50' throw 9,180 9237 10386 Not Recognized Top Miluveach 9.269 9326 10503 9403 9460 10648 Intermediate casing point 9,305 9362 10550 9427 9484 10680 Intermediate logging point 9,305 9362 10550 No logs run Top Kingak 9.791 9848 ] 1184 9793 9850 11164 Fault 49s1 - throw = 80' 10098 10155 ]] 584.7 10098 10155 11585 Top Sag River i 0,791 ]0848 12489 10761 10818 12452 Geol target #1 10.774 ]0831 12467 10774 10831 12467 Current Depth 10771 10828 12462 Intermediate casing point 10,825 10882 12534 10825 10882 12534 Top Shublik - 90 10.900 10957 12632 10900 10957 12632 Top Ivishak ] 0.990 11047 12749 10990 11047 12749 Total Depth 11,100 11157 12893 11100 11157 12893 Oil - Water contact 11,100 11157 12893 11100 11157 12893 Total Depth 11. 1 00 11157 12893 111 00 11157 12893 ~ - - ~-