Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
209-119
Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221118 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU F-29B 50029216270200 211147 8/20/2022 Halliburton SpinnerPressTemp PBU L-202 50029232290000 204196 10/24/2022 Halliburton PPROF PBU L-222 50029234200000 209119 10/21/2022 Halliburton IPROF PBU M-201 50029237110000 222030 10/17/2022 Halliburton IPROF Please include current contact information if different from above. By Meredith Guhl at 2:37 pm, Nov 18, 2022 T37276 T37277 T37278 T37279 PBU L-222 50029234200000 209119 10/21/2022 Halliburton IPROF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.18 14:44:07 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-222 PRUDHOE BAY UN ORIN L-222 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 L-222 50-029-23420-00-00 209-119-0 G SPT 4354 2091190 1500 1734 1746 1753 1754 50 81 82 81 4YRTST P Matt Herrera 6/25/2022 MIT-IA Performed to 2500 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-222 Inspection Date: Tubing OA Packer Depth 384 2509 2444 2426IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629123519 BBL Pumped:2 BBL Returned:2 Thursday, July 21, 2022 Page 1 of 1 STATE OF ALASKA eALASKA OIL AND GAS CONSERVATION COMMIQN , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed f 4 Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate H Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Schmoo-Be-Gone H 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-119 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-23420-00-00 7. Property Designation(Lease Number): ADL 0028239 8. Well Name and Number: ORIN L-222 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUF OIL 11.Present Well Condition Summary: Total Depth: measured 6340 feet Plugs measured 6121 feet true vertical 4849 feet Junk measured feet Effective Depth: measured 6121 feet Packer measured See Attachment feet true vertical 4689 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#A-53 29-109 29-109 1533 515 Surface 3367 9-5/8"40#L-80 29-3396 29-2877 5750 3090 Intermediate Production 6304 7"26#L-80 26-6330 26-4842 7240 5410 Liner Perforation Depth: Measured depth: 5682-5742 feet 5788-5838 feet 5860-5872 feet 5916-5940 feet 5996-6068 feet True vertical depth: 4386-4426 feet 4457-4491 feet 4506-4514 feet 4545-4561 feet 4600-4650 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 5682'-6068'. Treatment descriptions including volumes used and final pressure: S'i 19 Bbls Methanol,90 Bbls Schmoo-Be-Gone,1100 psi. tan�� f 4 `-.r; J iS 270 Bbls KCL,770 Bbls Diesel,63 Bbls 60/40 Methanol,30 Bbls 12%HCL,294 Bbls 2%KCL,65 Bbls 12%DAD Acid,887 psi- 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 203 120 161 Subsequent to operation: 991 340 881 14.Attachments:(required Per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG H GINJ 0 SUSP 0 SPLUG 0 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: 315-107 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature LL.44_4 t,.TPhone +1 907 564 4424 Date 12/2/15 Form 10-404 Revised 5/2015 vL //5714, RBDMV DEC 0 3 2015 //c/� Submit Original Only • L 45 L if) 45 L Y Y Y Y U U U (0 co N C3 aaa � -0 -0a 0 0 0 0 0 L L L L *L Q) 4) w Q) E E E E Q. 4) 4) N 2 CL d d 0_ L L L 45 4 W Y Y Y Y Ct3 (6 m m m m .f..i N N N N GD AAAA riMM E t V }fir N O) — in CO Cr) LO O) < > MOa7O N F, in 07 00 N '‘Zr • J Z •D O c L a O co Y2 M CO caIO ✓ CO U) 00 Lo Loa Q.YYYY >+000U d d 0_ d E N N N N Z N N N N J J J J • • a) Q� 000 � ca0 — ,ncov Ln O Ln 1� U N co 0 0 0 i co LC) () c L() N- N V CO r Ln N- 00 LO N CO N t CI I-- C7) 0) CO N N N N N c, Ln V C7 M N () CO CO C.) N Q N rnrncoNI- U) JN N N N N Z O p O N N• c0 0 J N J J = d It41 co .N N _ - CV O N O) 7 Co t N- V 0) �O CO O C co co co CD C'') CO CO J Z aO O N U U U ca D Q D C) kL) O O O Z Z Z rY O m m OD DD Uv) 0- I— H 0 • C x aa)) .- x co E 'C a) L a) o c 0 o U) 4 rn> rnc c0000 u" c)o o t Y m m 0) U) = c 2 c El o E N co u) c _ ii c E 0C -0 O7 Nr = co O o N a) co (IS oL -0I- U -O u_ -O a)� NOn O O a > -uC as Ut 0 ^ -c U) E > Nd' c L. II EL o N L � - J 0zE ° c) U -IOONU00 = 2 2 a u) 4-cn CC »O co Co Wa) N > 7:1O a o U) o 02e`) -. O O O 0_ u_ 4- S.- ) CO O - •7) a) a) u) v)O -- N Eco u) M co_ L a) u) � O J O O a)-.--,.. 4- p ‘ ? Ch _C a) 32 In co L CL E -00 ° cnJ o a) o � c � � Q\ � O ° b an u) m o C E a o cn -- oo 2 g L 2 o C (no Eo o > Cl- © D Uma 2 � _iU) o -1 Z O > N - = -Q J C U� N m U) U) O - - E +, E -a N d J _c � 0 — L _ u) ° ' _c cr) J c Q O a) Q +-. E F- �' m o v O . Ea ° p^ o E ° U ' 02 -J Co D)1Lci L0 co tVcna rn2Qm � Q diN Ou) � m aUN@O 0 co co . CO _ ~ c1 � � -0 _53 c -1,- 1-0 a) d �• E v w 0 p `.� �W 0 J U o a) 0 -a ca _5 d //, J C7 Ce J F- Q U Q> U) (0 6 l"Jm N m �_ J m m O a/ CLL. U) I- N 7p F- c QF- ad) N Jv1- Q .4- LI, p 't o _. cn1- Na - > 0 . >- (A - x oco � m co - Ln O O E c > a) � J F- i3 * F- F.5.t 'r) u? o O n- co- (N ,_ * Q ( co co ', U 5 .0) J5C - NOF- - 0 , H : O Ce L U) > U o a0 H a) QI- J_ _ J J ~ CN H ' Xu) N � cnmLL 5 o U � = - 0 W W � JN � F- LL) \ a o c H — 0 0 U) 8 3 0 0_aa to Qcc - m, W CO < J x J W N N J o E o �OoZra OQU) 0 ‹ QQr'•• o QU oh- 0 0-, LL. : _c -o oma a) -oZallom mm .- _ Co _ ,- Z E o �� Y a) „a-, UW a) a , NNZ ZO2u) O .- ZO _c -0 > � U) _'� co > _ � >� >� w W LaOZ Lo � w0 U) --a-3 o O ui o W a) c U) > > V U N _N O . a) > o -a a) Z0 cUa >, o -) Etppo -ao xNCC -a x0 to F- wZ > oo� al a `' WdHI- c\i a) c\iN- r, w a) N- "- 0 O7a -- ON `� � u> O 0 •J > wu- u-- Z oZZZO oZw ZV coacccccccc2cc � :F- L F- co a UH .�ws J220 � w H Q u) u) u) u) CI N- >, 0 CD 0 0 H o co Co 0 > N N Q • 0 a) E _ w m Cu U �l >O �u N - C V Cu 0 _0 N- 0 I 0 0 .aII) N c Q a) � E E (1) _a 2 H a) @�- Li _c _c w 0. c Lo O c U 0 � N � � I co U (0 N OD J E 0 a) RI c) N I U3 T(0 o N a) H a) a) o -0 o a) 2 a s C CO < ti op 0 _c J aco 70)co U -, 1 2 E C co D 0 o 7:3 Lu v) u) D b o 0 N b w' J O_ N 00 —(fl a Cu ? O O W O O ~ mrn pU CC m co c 0-� Cu 0 a) _1 Mit @L0 UN 0 2 0 0 LP: cJ 0, > U) °) Z 0 J ca 0 0 a) > p N U 0 E N N -J LL O tO > wC 2 2CtH - rnfn C e t+ Q' (np w N v O 2 — � U 0 0 Cu al i. w W0 p O O co Q O( /) W a co 0 p � J HD 0 Ln (1 Nw L c7E1 0. _1 � m HCS m w 2 2 MriW2 � � � O N Q zcn w � Cl) O O 0 m �r; wW '..7-.. = N - N m > w J w H Z u u 0 cU Q a) N J -� OJ 2 _ Q w �� w'ILI cH mO J a� Ect 4- Z UJ Lu pQ (nM CO H cn UJ J O W 0w �M1 Un Cu aU) O Q Q 0 m N N M J Q Q Q Q J Q - © _00_ m YD 0) �; 0 : m m Q � `n � .0 c * QO p w - - D N O * w w C° O XW Qv) wN Lo p O in H * ,_ _ Nn ELM'. 0 cn o G) 0 * � o o :) H -- U * _� ' Ce M � N OH cn �nrn �n � �n o �nm H (n � co a N N °es ix OD 0 N N N M N J >� < I I LU O �+ w m O N > (� sz 3 O _ X W M X X N M X c N- •ca a O6to QN Q _ N wti0o - . � 0 = z0m NF- 0 0 ,, \ m \ mch Y HZEt — — CZ w � D0Z H crO II- p OIi � O 11 ‘= w _p0 0 30 _a CU) DU) EL ao WLC0) cn cm mcn2W2m , -0 O -, ) D 9D Oz . ZN - I`-J -3D D -... 0--) -3DzE00 c15 _14'= :x H � NrI -a XN = f 'it W �IX73 HCtc\V CNH op 073 Z N Q X L0 22 b N- X U) > Z Z OD - L 1 Z Z 'T M '- Z o t' (_) 4) Ow atow ci - c Na, 000w w ° 0 OWMwriO 0 _02 0 0 mZ O O Z Z Z (0 0 0 0 0 0 0 o U 0 0 Z 0 H 0 0 :80 ,71 : _cr � N ( cc ctow : I N- 2 N : * 2w2U) : H N : Cuo L.r) in LU to La O O O o 0 N N N N N 6) O N M M M N- N- N- N- co II 10 c p 0 -o _ 112 U) E ca c) 0 co Ui 2 0 (a8 U) a) a) C p U (6 0 d 2 U O N 0 000 -0 06C U _10) 0 222 `I) O .g c0) in (j 0) ) Ow O N O O N ` 2 "- O - J 0 73 N- M V U J C COOpO O N p (n � 002 2 a) N Q -- -- -- 73 Et L0O1- cp (n (n m _1 _1 _1 Cl) o o '6 (0 w '- N- Q m � f/) U) 0) 4) a) a) u) (7) > W J EtO O O i) ibbob — C > > Y W O D O J W O C C.4- 0) .-- z,-, 0 a0o rn Q O— 00 N p E -- 0 0 Q m J 0 O Q N a CO (I) ��c151.0- 1.0 E D- - E Z Q J 0 cm w 0 o cj O I- d- N p w E J 2 m to _ (n (n CO a) *k *k *k J 2 a) a) (/) J t (/) (. Ln 00 H 0 OO 03 HHHbu) ' CO) Nir) = XNO O 0ZpZ UO L. v) (n u) ,r a0 Q Q w 03 O V a`) N- X O X co- c)c0 O In a ZZZa ' m U a) � c) o = in = ir) 2 2NH ii ON > > > 26N '7-- E ©,-, o1- 1- /- 1- 0 n O _ - N ZZZZW1-- N 000 ,1/4-JO , t7W W W LL LLc0cp0 W Q J �D � � LL � � � Jcnwg0000 CC � � vYYY � W rn CO- _Jen0000a000J _O _J a) J WP d CI) Z Q W' W' W _J 0) V U Q O O O M U (n HHH2 (5O Qm -IQa) NNNN QQ � 2w > W W Lu 0 : * U.1 CD m m � 100 p 0 * U0) UI- m100 * JLn0 ° aoeoco 'Co 0 : OWOH0 CC c L0or5o25otSU - OHH * to - r) ` ,,- * 1 _ 0mo0 (n O � w0 � c * � QJToH <- � <- To * ' 0E- © Z * m - M L>L L>L L>L O X W Jin `- u) J ' X X X X N ul N N Q Z (n O (0 O >+ > > > J 0-3 - m = W N N N N X - O X O *k O (/) - ' a) al OW' ) ' ZZ 10map O L < XJ _ _ _ - O co2OZH0 < 0o O O 0 OxxxI _ 0° 0z ct = m � mZZZZ - Z � � 00) I0Z CO a ,_ 10 010 00 LLHHF 3 WIC ouL30zw0 mdddNu) = inm mZZZ - - - - - v) mmU2 > N2m O 0_ 0 , , , � Z4nN O 0 W W W inN N N N Z 0 OZJ — O Y Y Y 7 D N N -' -) O O O N CO c0 O CO D ) D _ O '7 O O �' R' Q' Mcc x X H H to O in X N N N N W' H H N O M H 0 0 Z 0 0 0 0 N b b Z Z N r- = b - -i 1 a-' Z Z N O W Z 0 - OLU LLI UJ W _1 _1 Lu0 ONNN = YYYY W � 00W c%) W' 111 CL o U00 DDDDQ < < 4, UQQQQQQ < < < (°aUUQ W W DSU ? m * o_ a. o_ n_ 2 w rx * * cc oc oc oc oc cc ct DC 2 vi * * 2 u) u) d J * * H LO 10 10 10 O O O O N N N N N CO co co op co ID ID k X 0 $ w _ w [ c : E k 0 _[ £ § / ¥ ° c a) � o 5 / f 2 S - c c - 5 E 20EE / _c Z E * ƒ/ 2 t w , - E 2 -o k LI T / -J § $ w f a m 0 / / _ C o a & / co c, _1 k k o \ ƒ k , / c ƒ @ o / S COc � L = 2 I 0 2 0 He nEow / H � Z / 2 / R 2 (6F, $ _ 20 ELR m © Em / \ E \ 7 0 m $ �/ c >- »� ami / a 473 CO L. % 7ff ƒ RU ) / 7777 2 0. I H@ - < / G e m p < \ 0 / 0 � R � k % \ �_ k \ � � � £ - © E ® 2 / 0 , 2 I ¥ O g - co % � � w � � Ike Iq / E 2 N 0 - f \ ( / •N & / b � 2 / / 0 - E WS¥ � C) / Ro E / -a- 0r / f % E o O : = O C & 2 2 0 ( y t_ X Z < _ a `" - LL / k / % / \ k b / O i k ¥ _ , : / ® 6 G ix 2 & t w o 2 z r cc x G 7 Z_ 3 0 $ — U : � CO x \ /_ G ¥ _ « E / t \ 2 ƒ 0 O ' m'al 2E0 \ � m > m mz Z00k � h \ < © DE / ƒ � O � / � � / R ƒ ƒ ¥ / ƒ \ � �/ / / k Q Z / / / % , 2 Nb ? ? gib / > / / kZ � / � / e D c N k & & e -1 -30 _16 >, _ = i i x x G x 2 < - >< c-.i A A m E w m n & 2 0 m R = Z N r a b E b 2 b -ob -Z Z 2 - i E T3 7 N G = 7 O WT x- •- & - w R - / O O Z # c w \ L = -E c : < 0 < < < 2 < < D< < / / / w / H / / / / w < / / o/ : 22 w w 2 o_w o_ w a 2 w - : : m : 3 0 : : @ 2 : : 2 : L.0 n m \ / - \ \ e e co co a 7 r ( N N CO CO 6 8 6 • • .5 U N N .E N (,.0 .0 0 N N O L N N 0) 0 O i .*k a) w O ❑ 4) 2 W U m u) vi Q ~ J J Q 0 Z o 0 0 : -0 u) rn r J ~ 0 N m m -0 L7 Y a) CO CO o J C 0 m .S3 1) 3 3 (1) LL 0 0 CO O w o E 0 0 Lu Lu c' o + > co (Q — 0 3 I 0 L7 U) 0_ N a) I 2 N L J F" `� Q 00 0 W U) _1 N D O O N S Y = H - 70 w w 3 > c 0 > U F- N N ❑ H N. Q c Y CO r c J Z � � � * 0 0_ aJ �. C Z Lrn E W w (j ❑ W * N- r ❑ u) ❑ a� * — -0 > _. F- DW2 H U) ai W2 W2 0.aoJLC) 2 O N O Ln Q ~ N N Q ~ O Q ~ O O , Q 0. Or ❑ W N ~ __ F- OM W O Or OHLU OHILI ❑ O 0000 * d a7 M a) , ...c) = � ca � ❑ oin * O � � Ln � � � tri 2z (5 " �oo * N * �` V ZLU * J V J V O U) >+ �' N D V O LU r O X Q Q N In Lo Y LU f- Y W N M D Q M E '4") Q u- 21❑ N ❑ OZ - `" ~ W 500 a> M ❑ 06 1J/3 W ❑ ~ fj ❑_ ~ c — O w W _ _ ❑ ❑ — ❑ ❑ J ❑ -oO' ❑ — ❑ ❑ _ ❑ ❑ 0 D � ❑ WUwz ©Wwz E OrzUWzUgUWz �3U5 ❑ z E u) r ZD - = 2Q2 — � 2cC — 04- o — Q2 — NQ2 = o � o � mN rI ❑ r % OCQZ4- 0) - Z ❑ w ? % ❑ 1 � % N = 12 -0 — z � O = OOHOwQ m ° a�) Oa0 (� Ha00HF - 0 � Oa O M N ❑2 r2 i 00 LL m U C N C U ❑ ❑ (n M CV C N ❑ `_ WDWY ❑ W 0C :=. (n - CC � WY ❑ DWY ❑ ❑ � oc :_. -0 . 013:1M JMaLOLa c oLZU) g ..,u) _ a_ cc � OLa. ccJJ () (>n g a = ZJF- U) 0007F- J07Q5U2uU > 00u) F- J00 (nF- JJF- > U EU * Q D W CC J cC W D cc F- * * 0 * * J Q' W D J Q' W D D W * * = : CC d (/) J w J u) d J U) : : 2. : : u) J U a. (/) J u) o_ a. u) : a. : U) U) U) U) O r O r �--- r O O N N N N a) O O N Cr) CO M O O O O r r r r 0 • 0 Y cnJ m m O CO C 3 a as O 0 E 'ill w E ca I E N L (f) 7 O.. 0. J CO N -0 LL 5 7 — C%1 Q W4 Q eo a0 E 0 I * D 2 * O ?� J * 0 * (0- * to = F- C F- 1 H IC) F- Z ,- cn � cn0a ocn ocn ocn * — acnes- ✓ SMF- YF- iNO _ LU F- 2UJ F- 2F- � M 2wz (n O Dowc) wci' R V W � W MUJ � w0LL d g < 0) < I6ob0 poQp °OQ .- 2D � Q � -1 re OrJ z2 2mfx2 � 1 - 02Lna = J txa0a ©v) - @�a _ Ufa _ Uaazr _ UdaJ A W W Y W U) V N W v_ W �N,) ,r W O LL O W } w 7111 CDL6 °515; gO * c% O4# (% O4tt6pQO * t3F- � O ; aCIoCI) oL ) om5; o1 °) 0DDL6 0SF- zw5w _zw@�zw ©zW ©zwzz@�zwww W I-OWOOa " uOWOC 06 U U � � F- F- E- %-) ou) 5LLcn5u- cn � n �r-N 17 � MO co� � 4 � � U a W DWYW " YW "' YW YWW W YW a 6 2 U J Q cnaaaa Jannm Nm = U0� a � OC � OC � � E o cnDou) Hcn -1Hu) -1 u) -1Hco 5 -1HnJJ cn - o oO *W J W' W W W W' W W' W W' * * W W D * U U O N N * J U) J (n J a u) J a U) J a U) J * * a U) J a * (n Y LI (O N v- Lf) In O O 0 N N 15 0 0 M O cD U) M 17 m O N O M N O O ~ 4 ! IY NOTES:'^ WELL REQUIRES A SSSV WHEN W =ELLFEADFMC L-222 ON MI"' ACTUATOR= CNVLEO NRAL KB.ELEV 79.10' I ` J BF.ELEV= 48.1' 26' —4-1/2'X 3-1/2"XO,D=2.992" KOP= 400' Max 20"COhDUCTOfZ H 106' r Max Angle= 50° 5428 2806' 3-1/2"FEs X NP,D=2.813" Datum M)= 5820' 91.5#,A-53, Datum TVD= 4400"SS ID=19.124" , 9-5/8"CSG,40#,L-80 BTC,D=8,835" H 3396' 4250' H ESTIMATED TOC N 7"LNR 7"CSG,26#,L-80 TCI X0 TO L-80 BTC — 5154' X X GAS LFT MANDRELS 3-1/2'MARKER JOINT w/RA TAG — 5553' * ST M) ND DEV TYPE VLV LATCH PORT DATE Minimum ID =2.75 " @ 6121' Ir 8 5593 4327 49 MAG Ct1Y RK 0 04/04/10 3-1/2" HES XN NIPPLE I I 5613' H3-1/7FES xNP,D=2.813" 5660' H3-1/2'NDPG MULTI-SENSOR SUB,D=2.992" 7"X 3-1/2"BKR R213M PORTS)PKR,D=2.875" H 5633' j--XI / WATER INJECTION MANDRELS 7'MAFEH JOIYTw/RA TAG — 5649' ±-11 / ST M) TVD DEV TYPE VLV LATCH PORT DATE iv/ 7 5670 4379 48 MMGW P-15XJR RK 17 11/12/14 6 5739 4425 48 MMG-W 'DMY RK 0 09/24/12 IIIP [il 5 5793 4461 47 MMG-W DMY RK 0 11/08/09 4 5832 4487 47 MM3-W P-15XJR RK 15 11/12/14 3 5899 4533 47 MMG-W DMY RK 0 11/08/09 2 5940 4561 47 14/1G-W P-15XJR RK 11 11/12/14 1 6082 4660 44 MMGW P-15XJR RK 18 11/12/14 I 'STA#6 HAS MJDF®DMY 7'X 3-1/7 BKR REM PORT®RCF,13=2.875" —I 5764' >/ �\ 5753' �3 1/2"FES X NP,D=2.813" ■ 5776' H3-1/2"NOM MULTI-SENSOR SUB,13=2.992" MI 0 . 5861' Hr X 3-1/2"BKR PREiM PORTED PKR,D=2.875" 1-05868' H 3-1/2"NDPG MULTI-SENSOR SUB,13=2.992" ' ' 5888' H 3-1/2'FES X NP,D=2.813" m n PERFORATION SLJN1MRY REF LOG:tJSfT ON 11/17/09 5969' -f7"X 3-1/2"BKR PREM PORTED PKR,D=2.875" ANGLE AT TOP PERF: WA Note:Refer to Production DB for historical perf data 1 { 5986' I-131/2"FDFG SINGLE-SENSOR SUB,ID=2.992' SIZE SPF ZONE NTERVAL Opn/Sqz SHOT SCIZ 4-1/2' 5 OA 5682-5742 0 11/06/09 I , [..] 6051'�-13-1/2'HES X NP,D=2.813" 4-1/7 5 OBa 5788-5838 0 11/06/09 4-1/2' 5 OBb 5860-5872 0 11/06/09 6100" —3112"FES X NP,D=2.813" 4-1/2" 5 OBc 5916-5940 0 11/06/09 4-1/2" 5 OBd 5996-6068 0 11/06/09 6121' H 3-1/2"FES XN NP,13=2.750" 6121' —3-12'FIND(PLUG w/DMY VALVE 3-1/7 - TBG,9.2#,L-80 TC1 .0087 bpf,D=2.992" H6142'/ PRONG SET (11/11/14) \ 6144' H3-1/2'VVLEO,D=2.992" FBTD — 6243' 1111111111 7"CSG,26#,L-80 BTC,.0383 bpf,D=6.276' —I 6330' 111.1.141/111.1.111.1 DATE REV BY CO14WNTS DATE REV BY COWENTS ORION UNT 11108!09 MES INTIAL COMPLETION 05/27/13\AECJ PJC WRF C/O(05/24/13) WaL: L-222 0427/11\ICM'PJC GLV CJO(0421/11) 11/11/14 CIN/PJC PILL PLUG/SET RSD(ON PRONG FERMI No: 2091190 04/28/11 AW PJC PULL C-SW(07/13/11) _ 11/12/14 CJWPJC WFR C/O AR No: 50-029-23420-00 09/26/12 BSE/JM5 WFR CJO(0924/12) 02/24/15 GCJJMD FIXED OKB SEC 34,T12N,R11 E,2369'FSL&1522'FWL 01/23/13 CDJ/JMD VVFRC/O(01/08/13) ' 0527/13 VVEC/PJC RLL/RESET PXN(04/24/13) BP Exploration(Alaska) yOF T�� hw\,\\��/,�s� THE STATE Alaska Oil and Gas �„-s_r �, of Conservation Commission _ ALASk:A tits=--f 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OF ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Brenden Swensen Production Engineer SEAMED '''' f BP Exploration(Alaska), Inc. dog " 1\- f P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, ORIN L-222 Sundry Number: 315-107 Dear Mr. Swensen: 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, . , /a. pe._tyjc&._ Cathy '. Foerster / Chair DATED this ( "-day of March, 2015 Encl. . RECEIVED STATE OF ALASKA FEB 2 5015 ALASKA OIL AND GAS CONSERVATION COMMISSION 9--TS �j�/I 1-- APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Weill: Stimulate❑ - Alter Casmg❑ Other. 5 6(1/4 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 209-119-0 . 3.Address: Stratigraphic ❑ Service 0 , 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23420-00-00 . 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? ORI N L-222 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): /j.. z z..4,zr- 10.Field/Pool(s). OL.OC cZ 2:5E.ADL0028239" PRUDHOE BAY, SCHRADER BLUF OIL 11. / PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 6340 4849 . 6121 4689 6121 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#A-53 29.45-109.45 29.45-109.45 Surface 3367 9-5/8"40#L-80 28.95-3395 97 28.95-2876.81 5750 3090 Intermediate None None None None None None Production 6304 7"26#L-80 26.33-6329.89 26.33-4841.68 7240 5410 Liner None None None None None None Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size• Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type• See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service E ' 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG 2 , Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brenden Swensen Email Brenden.Swensen@BP.Com Printed Name Brenden Swensen Title Production Engineer Signature ` Phone 564-4887 Date 2/2y/16 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 — I OT Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Et/ Subsequent Form Required: /0 — 4 h 4 S,..4 APPROVED BY /Approved by. COMMISSIONER THE COMMISSION Date: 3-C-/-S- 7 /eh -3 -A -/4 , .0› z• zz /� Form 10-403 Revised 10/2012 O R fiGvIdli�b ���-li iQn is valid for 12 months from t e date of approval. Submit Form and Attachments in Duplicate VTL 3/5 //S , ` �' 11 /// RBDMS APR - 2 2015 ,#4-55 5- • Perforation Attachment ADL0028239 Well Date Perf Code MD Top MD Base TVD Top TVD Base L-222 11/12/14- STO 5682 5742 4386 4426 L-222 11/11/14 STO 5788 5838 4457 4491 L-222 11/12/14 STO 5860 5872 4506 4514 L-222 11/12/14 STO 5916 5940 4545 4561 L-222 11/12/141 STO 5996 6068 4600 4650 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF a) C) LO CO CO CO CO Q J J J J N Q co co) O 0 O Ln O LO U • 7 O O O O L McL1) CO CO LO N N- 0 CC) N- LC) CO N , N N LC) CO• 0 d f— LO CO CO N N-- (NI — N V •I- C2 O 0 co O V LO Q N N N N L I CU EM a) C C om 0) O so, Ln 4- (�J c) CO CO N w co M CO p 2 CD C J N Q HrnCO rnNtLc) U N N N N N Co O O Q coi J J 4:k co N LO O CV (n CO 0 N � N N 0 � M L_ I� 0) 0 0 O CO C00 () J CO CO CO • Z 00 w U 0 0 0 �Z Z ZOIY0003 OCCDDD 00_ U) HH bP To: AOGCC Date: February 17, 2015 From: Brenden Swensen, Orion PE 907-564-4887 Subject: L-222 Acidize Stimulation Step Unit Operation 1 S WFRV change outs for zonal acid stimulation 2 F Acidize HISTORY L-222 is a Schrader Bluff injector configured to selectively inject into the OA, OBa, OBb/OBc, and the OBd to support L-201. The well has a history of poor injection conformance due to plugging valves. Most recently, the water flood regulator valves (WFRV's) were replaced on 11/12/14. The well was placed on injection and within hours all valves were plugged. The plan forward is to perform a Schmoo-B-Gone on the flow line (it is believed that the surface kit could be contributing part of the issue of solids/plugging down hole) and back flow it into- an adjacent well. From there, a DAD acid treatment of the wellbore and each zone is to be performed to clean up any schmoo that is down hole (imitating MPI-16's program and success). Lastly, new valves will be run to ensure valves are in working condition. OBJECTIVE The objective of this program is to perform a Schmoo-B-Gone treatment on the surface flow line, acidize the OA, OBa, OBb/OBc, and the OBd, and replace water flood regulator valves. PROCEDURE 1. RU, hold pre-job safety meeting, PT 2. Pump 45 bbls Schmoo-B-Gone in the flow line taking returns down L-103. 3. Dummy the OA, OBa, and OBb/OBc. 4. Pull WFRV from OBd. 5. Pump 30 bbls of 12% HCI and soak OBd perfs. 6. Flush with 30 bbls of 2% KCI, over flush with produced water. 7. Dummy OBd. 8. Pull dummy from OA 9. Pump 25 bbls of 12% HCI and soak OA pens. 10. Flush with 30 bbls of 2% KCI, over flush with produced water. 11. Set dummy in OA 12. Pull dummy from OBb/OBc 13. Pump 15 bbls of 12% HCI and soak OBb/OBc perfs. 14. Flush with 30 bbls of 2% KCI, over flush with produced water. 15. Set dummy in OBb/OBc 16. Pull dummy from OBa 17. Pump 20 bbls of 12% HCI and soak OBa pens. 18. Set dummy in OBa 19. Pressure test tubing 20. Replace dummies in OA, OBa, OBb/OBc, and the OBd with live WFRV's 21. RDMO SL • TREE= 4'CAM Act!HEAD t • L-222 NFM;r V 1,1- SSW:, WELL REQUIRES A SSWHEN ACTUATOR- CIA -. NML Ka.ELB, 78-6 ` aF.ata( 48.P 26' ] 1 1 ,,.- 1,2- xr ,R•xe KOP= 40TY ri At3x Arms- 571"0 5428 20'C%)r4Jl1r:T[TR, -L 106' Datum A0 5820 91 0a,A-53, 1 1 1 2000' —f3 1,, 1 1 x rip,10=2 sir 1 ,Datum 1VD= 4400" ^ D'19 124' Io-Sle•CSG,40Y.L-80 8TC,I)=8.835'J-j 3396' 14 i 4250' I -1ESTI MTED TOC N r UV r cc 26p..L 80 TC7 x0 10 L8(1 BTC - 6154' —^ -- LFT A 3-117MARKER JONTw1F44TAG 5553'--- ST WU ivULV 'O�T'rt VMLITOI FORT DATE 8"6693 4327 49 HMG OW - RK 0 04704110, Mln4num1D>+2.75"@ 6121' 1:31- j3-1/2"HESXNNIPPLE 1 1 5613` (310Th"1Na',D•2813•_, ITX3-V!81CRPREMPORTIDPKR1D-2a75' H 5633' 1— 50450.-1-13-7-1t7 wrrrmt.ns17f072�txi 29471 WATER 14JECT1014 MANDRELS 144.141F1i JON1 N 1 RA TAti J564$` IVO DEV DATE T 5670 4319 48 ATY F W P-7YPE L5X#t PORI17 11/12711 El n 6 5733 442S 48 M t,-W '1 AY RK 0 0972471 2 5 5793 4461 47 AMGW DRAY RK 0 11/08/09 4 5832 4487 47 AMGW R15Xit RK 15 11112114 1i 3 51399 4533 47 MAGW DA11 RK 0 11706109 7 5940 4561 47 4G-W R15X,1 RK 11 11712714 1 6082 4660 44 AMG W P1611.11 RK 18 11717714 1i'STA 56 WAS MOCI[D DHA 13"X3 V7'F#1414144 NA 1[)1(H1)1Kit 1)-2875' 1--U5764' 1 X l i„"a112"tfSxImo,t7 2813 Uf 5776' -131t2"NEM AILTFSB490R SUB,D-2.997 I x_EiL.,._. 5851' I-IrX3 ter KKK(48-NA(0Hr1-L)F4C(t.D-2am* ] 1 ii 5668' I 13 117 MCC MULTI Se-SCR SUB,D=2.092' j 1 1 66.+s' 11 LT'ill”.% S,8 2 HIT j © El PERFORATION WAPITI REF LOG:US&T ON 11/17709 z 6989' -I r x 3 V7 RIM(44M PORI!1)1402,1)-•2 8!Y ANGLE AT TOP PEPF NA Nobe.Reef b Ptoduction DB Tor historical pert data 6666' I 13 1E7 NUL;:i8 i I i1 N IN 2:;1113.It) 7 EMC SEE SPF ZONE NTBiVAL Opn(S1u y SHOT Sol 4112" 5 OA 5682 5742 0 11/06/09 1 , D ' 6051' 1-13.1/2-11 X NP,D-2 613" 4-1/2" 5 08e 5788-5838 0 11106109 Eil 4-112' 5 Cab 5860-5872 0 :11106109 4.1R" 5 OBc 5916 5940 0 ;11106109 I I 6100' I I, 1 i F!:?S X NP.D-7 81 r I 4 92' 5 064 5986 606E 0 i ti(061091 6121' 1--f33V2'8 3 XNNi'D=2751:17 6121" ' 31/2 ono 11uuwi(IVY VAlVI 13-117 TERG,9 24,I-80 TCI, 0687 bp`,D=2 997 H-{ 6142' , . PRONG 9[=1 (11111114)--____ f1711114)1____ 6144' -1 3 yrwr D-7Dor I Pam t", 6243 141'1+4.44.41 I r CSG,268,L-80 81C,.0383 bpi,13-8.216 j- 6330• --- i.�1:/.�1.� - DATE REV BY COM ENTS ATE FS/G P.JW18-SY 004.611106MOHMOH UNIT11108/09 IVES INTIM.COMPLETION 105127/13 lAEC: CYO((7/74,'13) A81 I, 1-222 04127711 1/CM PJC GLV GO)04121+11) i 11111/14 G19PJC RLL RAG SET 19 VC CN1 PRONG RIMY No:'1091190 0425111 AFI PA.ril E G51.x3(0013111) 11117(14 CANYRIC NPR C IO APItb. 50-029-23420.00 09126/12 135641717)AFR 00(09124712) I SEC 34,T12 1,UTI IE,2369'FSL 8,1527 MA 01123,/13 CAN..M7 M RCID{01708113} --1 05127713 WEA'PJC Rn t RESET PXII(04(24113) BP Exploration(Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2091190 Well Name /No. PRUDHOE BAY UN ORIN L -222 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23420 -00 -00 MD 6340 ND 4849 Completion Date 11/8/2009 Completion Status WAGIN Current Status WAGIN UI Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes (----''-- DATA INFORMATION • Types Electric or Other Logs Run: DIR / GR, DIR / GR / RES / NEU / AZI DEN, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type ed /Frmt Number Name Scale Media No Start Stop CH Received Comments C Lis 19084 ~Cement Evaluation 10 6206 Case 12/3/2009 LIS Veri, USIT, CCL g Cement Evaluation 5 Col 20 6203 Case 12/3/2009 USIT w /Inclinometer, CCL, GR, GPIT 7- Nov -2009 C Pds 19090 -Cement Evaluation 20 6203 Case 12/3/2009 USIT w /Inclinometer, CCL, GR, GPIT 7- Nov -2009 /og Induction /Resistivity 25 Blu 45 6304 Open 1/26/2010 MD Vision Service og Induction /Resistivity 25 BIu 45 6304 Open 1/26/2010 TVD Vision Service C 19213uction /Resistivity 48 6337 Open 1/26/2010 EWR logs in TIFF and PDS ED C Directional Survey 0 6340 Open - pt Directional Survey 0 6340 Open Well Cores /Samples Information: II Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2091190 Well Name /No. PRUDHOE BAY UN ORIN L -222 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23420 -00 -00 MD 6340 TVD 4849 Completion Date 11/8/2009 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? 'L? Daily History Received? / N Chips Received? Y_L.N - - -- Formation Tops N Analysis Y71V' — Received? Comments: Compliance Reviewed By: — Date: _ C__V 14 • 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 04, 2010 TO: Jim Regg L2/ //c P.I. Supervisor q SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -222 FROM: Chuck Scheve PRUDHOE BAY UN ORIN L -222 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN L -222 API Well Number: 50- 029 - 23420 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS100729104606 Permit Number: 209 -119 -0 Inspection Date: 7/28/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -222 "JType Inj. 1 W' TVD 4354 ,i IA 1320 4000 ' 3920 3920 P.T.DI 2091190 TypeTest SPT Test psi 1500 OA 740 960 960 960 — Interval - p/F P - Tubing 1475 1500 1500 1500 Notes: Pre -test pressures were observed for 30+ minutes and found stable. Packer TVD taken from operator report, not calculated in data base. Wednesday, August 04, 2010 Page 1 of 1 • Page l of l Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Tuesday, August 03, 2010 3:44 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU L -222 / PTD # 209 -119 Hi Art, Please reference the following well: Well Name: PBU L -222 Permit #: 209 -119 API #: 50- 029 - 23420 -00 -00 Top Perf MD: 5682' Bottom Perf MD: 6068' This well began Injection on July 24, 2010 Method of Operations is: Water Injection There is no test data for injection wells. 8/6/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks@alaska.gov; tom.maunder @alaskagov; doa .aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT/ PAD: Prudhoe Bay / PBU / L Pad DATE: 0728110 OPERATOR REP: Jerry Murphy AOGCC REP: Chuck Scheve Packer Depth u Pretest Initial 15 Min. 30 Min. Well L -222 Type Inj. W TVD 4,354 Tubing 1,475 1,500 1,500 1,500 Interval I Pt *... P.T.D. 2091190 Type test ` P Test psi 1500 Casing 1,320 4,000 3,920 3,920 P/F P Notes: MIT -IA to 4000 psi post initial injection I OA 740' 960 960 960 P.T.D. I T s i TVD �J Tubing Interval Notes: I I OA Well Type lnj. TVD Tubing Interval P.T.D. _ Type test_ I Test psi Casing P/F Notes: OA TVD Tubing P.T.D. Type test I Test>si Casing Interval Notes: OA P.T.D. _ Type test) I Test psi' Casing Interval 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 = Dilferertial Temperature Test O = Other (describe in notes) 0 MIT Report Form BFL 11/27/07 MIT PBU L -222 07- 28- 10.xls 1 -- • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 31, 2010 g ✓ li / r n P RECEIVEL d--+ Mr. Tom Maunder APR 0 7 2010 Alaska Oil and Gas Conservation Commission 01&1@M. COOKINIOLD 333 West 7 Avenue Anclidage Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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, API and PTD numbers, 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, Torin Roschinger BPXA, Well Integrity Coordinator 1 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) L pad Date 3/31/2010 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ sealant Well Name PTD # API # Initial to. of cement •um.ed cement date inhibitor date - -- ft bbls ft na MTIMI L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L -02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L -03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L -04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L -100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 ®i 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 ®i 2020360 50029230710000 37' NA Need To. Job? NA -- 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L -104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L -105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L -106 WM= 50029230550000 NA 2.75 NA 28.05 5/6/2009 L -107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L -108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L -109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L -111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L -112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L -114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L -115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L -116 2011160 50029230250000 5 NA 54.4 6/28/2009 L -117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L -118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L -119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L -120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L -121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L -122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L -123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L -124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L -200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L -201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L -202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L -204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L -205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L -210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L -211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L -212 2050300 50029232520000 NA 1.8 NA laiMill 6/26/2009 L -213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L -214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L -215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L -216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L -217 2060750 50029233120000 date blockin. conductor NA NA L -218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L -219 2071480 50029233760000 surface NA NA L -220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L -221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 .:.,6:%1.`-(::::,7Y4 "'' r t r y te er . , - :,.: S ; t ". $ 4 * & -, 754._.527" * '..L' aaf €s:I, :::04 `v*�r� ,11" . ..*. is��n ..' sk,. . »,. x .. L -250 • r 50029232810000 NA 3.4 NA 34 6/26/2009 L -50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L -51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 NO. 5378 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPJ-19A 6581-00020 US 1"4-% 1 c2f2) 12/19/09 1 1 W-25A AXBD-00063 MEM LDL ,._.. C; - //) / PO 5 _ 12/14/09 1 1 W-25A AXBD-00061 MEM PROD PROFILE _0(A .- /() i .199 n 12/14/09 1 1 07-26 BALL-00007 RST _J.K,'3 -ActIr / .9 tif _ 12/08/09 1 1 , X-10 BALL-00001 PRODUCTION PROFILE ROQ - n 19,- 11/30/09 1 1 X-13A BALL-00002 PRODUCTION PROFILE 3 -() A ( 9 g Aga 12/02/09 1 1 GC-2E B5JN-00027 PRESS/TEMP SURVEY, 143'1- -6 I fi jafa _ 12/08/09 1 1 B-16A AZCM-00049 GLS 0 4111 ) -. C)(4 a. . , -, ,,6 12/04/09 1 1 W-25A AWYZ-00004 MEM DDL An all - /() g., , ,,Q 4 _ 12/08/09 1 1 2-16 B5JN-00029 PRODUCTION PROFILE LIP - i n i 1 2Q, 1 12/10/09 1 1 err k. X-32 L-210 B5JN-00024 PRODUCTION PROFILE 13 1 -/ ( 0 1 -- ,0Z2 AYKP-00058 PRODUCTION PROFILE / Ie-/-03q_ / in 11/29/09 B2NJ-00043 MEM INJECTION PROFILE ...,. - " " - 12/04/09 1 12/01/09 1 1 1 1 X-25 1 (...") L-222 S-218 . 11-10 09AKA0176 OH MWD/LWD EDIT • litiMPAIIIIIWW,,, 10/12/09 09AKA0148 OH MWD/LWD EDI soc _I ict I - 0 _ 11/03/09 2 1 AZCM-00046 RST 1 Inj - 1 '9 ariy AP30-00066 RST ( y r.& f 75- i 5 - / :-....)31 10/31/09 1 1 11/01/09 2 1 1 2-08/K-16 1 ■ , . ■ ' . 1. _. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 0, BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 jA 1 ■ :',,S ,•• • ( • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 4 2009 WELL COMPLETION OR RECOMPLETION REPORT �11iNsiralmm r.nns. C:nmmissien 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended 1b. Well Class: dd ,g 20AAC 25.105 20AAC 25.»0 ❑ Developmerie ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One =' Service ❑ Stratigraphic 2. Operator Name: 5 ' ateCom. Susp., orAbar�.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/8/2009 209 - 119 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 10/29/2009 50 - 029 - 23420 - - 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/3/2009 PBU L -222 2620' FSL, 3501' FEL, SEC. 34, T12N, R11E, UM 8. KB (ft above MSL): 79 15. Field / Pool(s): Top of Productive Horizon: 3167' FSL, 357' FEL, SEC. 34, T12N, R11E, UM GL (ft above MSL): 50.5' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD +TVD): Schrader Bluff 3237' FSL, 105' FWL, SEC. 35, T12N, R11E, UM 6243' 4778' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 583412 y- 5978344 Zone- ASP4 6340' 4849' ADL 028239 & 028238 TPI: x- 586549 y- 5978926 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 587010 y- 5979002 Zone- ASP4 None 18. Directional Survey: 1E1 Yes ❑ No 19. Water depth, if offshore: ' 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1732' (Approx.) It. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR, DIR / GR / RES / NEU / AZI DEN, USIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM To I BOTTOM SIZE CEMENTING RECORD PULLED 20" 129.45# X -65 Surface 108' Surface 108' 42" -260 sx Arctic Set 9 -5/8" 40# L -80 29' 3396' 29' 2877' 12 -1/4" 525 sx Arcticset Lite. 426 sx Class 'G' 7" 26# L -80 26' 6330' _ 26' 4842' 8 -3/4" 283 sx Class 'G' 318 sr - /2.44 • 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD 'tr If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) CKER SET (MD / TVD) 4 - 1/2" Gun Diameter, 5 spf 3 - 1/2 ", 9.2 #, L - 80 6144' 5633' 4354, 5764' / 4441 MD TVD MD TVD 51' / 4500, 5969' / 4581 5682' - 5742' 4386' - 4426' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5788' - 5838' ' 4457' - 4491' 5860' - 5872' 4506' - 4514' DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 5916' 5940' 4545' 4561' 2388' Freeze Protect w/ 84 Bbls of Diesel 5996' - 6068' 4600' - 4650' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 0: No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presen.- • •; • as or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resu I12 4.071. I tig_97 c.V None Form 10-407 Revised 07/2009 CONTINUED ON REVERSE K P1 14 1 1 Sbmit Original Only 29. GEOLOGIC MARKERS (List all formations and n rs encountered): 30. •ORMATION TESTS NAME MD TVD Well Tested? ❑ Yes No Permafrost Top 29' 29' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, a nd submit Permafrost Base 1848' 1761' detailed test information per 20 MC 25.071. Ugnu 3388' 2871' Ugnu MB1 5183' 4058' None Ugnu MB2 5209' 4075' Ugnu MC 5335' 4159' Schrader Bluff NA 5445' 4231' Schrader Bluff NB 5486' 4257' Schrader Bluff NC 5528' 4285' Schrader Bluff NE 5543' 4294' Schrader Bluff NF 5627' 4350' Schrader Bluff OA 5682' 4386' Schrader Bluff OBa 5789' 4458' Schrader Bluff OBb 5959' 4574' Schrader Bluff OBc 5918' 4546' Schrader Bluff OBd 5995' 4599' Schrader Bluff OBe 6089' 4665' Schrader Bluff OBf 6159' 4716' Base Schrader Bluff OBf / 6224' 4764' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 6224' 4764' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. �) Q Signed: Terrie Hubble /� Title: Drilling Technologist Date: 7-VD l IY�- PBU L - 222 209 - 119 Prepared ByName/Number. Terre Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Zach Sayers, 564 -5790 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only I I BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: L -222 Common Name: L -222 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 11/1/2009 LOT (ft) (ft) (ppg) (psi) (psi) (ppg) 11/2/2009 LOT 3,426.0 (ft) 2,876.0 (ft) 8.80 (ppg) 640 (psi) 1,955 (psi) 13.08 (ppg) 11/3/2009 LOT (ft) (ft) (ppg) (psi) (psi) (ppg) • Printed: 11/19/2009 11:37:10 AM • r BP EXPLORATION Page 1 of 11 operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/27/2009 20:00 - 00:00 4.00 MOB P PRE PJSM. PREP RIG TO MOVE DOWN WELL ROW FROM L -2231 TO L -222i. DISCONNECT PITS AND MOVE AWAY FROM SUB; MOVE SUB OFF WELL. 10/28/2009 00:00 - 02:00 2.00 MOB P PRE PJSM. MOVE SUB OFF OF L -223i. SPOT CRANE AND MOVE ANNULAR AND DIVERTER FLANGE FROM BEHIND DOUBLE MASTER; SPOT AND PLACE ANNULAR PREVENTOR AND DIVERTER FLANGE ON L -222i CONDUCTOR. 02:00 - 03:30 1.50 MOB P PRE SET MATS, HERCULITE AND CELLAR GRATING. INSTALL FIRST JOINT OF DIVERTER LINE BEFORE SPOTTING RIG. 03:30 - 05:30 2.00 MOB P PRE MOVE NABORS 7ES SUB DOWN THE WELL ROW FROM L -223i TO L -222i. SPOT RIG OVER WELL SLOT. 05:30 - 08:30 3.00 RIGU P PRE SPOT PITS, REMOVE OLD CEMENT FROM FLOW LINE. 08:30 - 10:00 1.50 RIGU P PRE CONNECT PITS, MU DIVERTER LINE. BERM PITS AND SUB. INSTALL VALVES ON CONDUCTOR AND SPOT CUTTINGS BOX. 10:00 - 12:00 2.00 RIGU P PRE NU DIVERTER SYSTEM NU 20" RISER ON HYDRILL AND TURNBUCKLES. 12:00 - 16:30 4.50 RIGU P PRE RIG ACCEPT @ 12:00, 10/28/2009. TAKE ON WATER, LOAD AND STRAP 4" DP IN PIPE SHED. REPAIR IRON ROUGHNECK. CHANGE LINERS OUT TO 5.5" FOR SURFACE HOLE. 16:30 - 22:30 6.00 RIGU P PRE PU JOINTS OF 4" DP AND HWDP. RACK BACK 30 STANDS OF DP AND 7 STANDS OF HWDP. PU AND RACK BACK JARS. 22:30 - 23:30 1.00 RIGU P PRE PU STAND OF PIPE AND RIH; FUNCTION TEST DIVERTER, WITNESS OF DIVERTER TEST WAIVED BY AOGCC REP JOHN CRISP. PERFORM DIVERTER DRILL AND TEST GAS DETECTION SYSTEM. 23:30 - 00:00 0.50 RIGU P PRE PREP TO PU 12 -1/4" DRILLING BHA; BRING BIT, STABILIZERS AND CROSSOVERS TO RIG FLOOR. 10/29/2009 00:00 - 03:30 3.50 RIGU P PRE PJSM. MU BHA #1: 12 -1/4" MXL -1X TRICONE BIT, 1.5DEG BEND MUD MOTOR, DRILL COLLARD, MWD LOGGING TOOLS, UBHO, DRILL COLLARS, FLOAT SUB W/ NON - PORTED FLOAT AND JARS. 03:30 - 04:30 1.00 RIGU P PRE RU GYRO SURVEY. 04:30 - 09:00 4.50 DRILL P SURF PRESSURE TEST SURFACE EQUIPMENT. SPUD WELL; CLEAN OUT TO BOTTOM OF CONDUCTOR AND DRILL AHEAD TO 264' MD. 40K UP, DOWN AND ROTATING. 550GPM AND 675PSI. WOB = 5 -10K. 09:00 - 11:00 2.00 DRILL P SURF POOH AND RACK BACK 2 STANDS OF HWDP; PU REMAINDER OF BHA AND RUN BACK TO BOTTOM. -5' OF FILL ON BOTTOM. 11:00 - 12:00 1.00 DRILL P SURF DRILL AHEAD TO 274'. GYRO SURVEYS EVERY STAND WHILE DRILLING. 48K UP, 45K DOWN, 47K ROTATING. 5 -10K WOB, TORQUE = 1.5K ON, 0.5K OFF. 0.95 HOURS SLIDING, 1.83 HOURS ROTATING, 2.78 HOURS TOTAL DRILLING TIME. 12:00 - 21:00 9.00 DRILL P SURF CONTINUE TO DRILL 12 -1/4" SURFACE HOLE FROM 274' TO 813' MD. 60K UP, 56K DOWN, 55K ROTATING. 1110PSI ON, 1034PSI OFF @ 550GPM. 2K TORQUE ON, 1.5K OFF @ 14K WOB. 1.35 HOURS SLIDING, 4.07 HOURS Printed: 11/30/2009 4:26:10 PM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/29/2009 12:00 - 21:00 9.00 DRILL P SURF ROTATING, 5.42 HOURS TOTAL DRILLING TIME. 21:00 - 21:30 0.50 DRILL P SURF CIRCULATE BOTTOMS -UP X2 AT 558GPM AND 1036PSI. 21:30 - 22:30 1.00 DRILL P SURF MONITOR WELL; 8.7PPG IN AND OUT. POOH FROM 813' TO BHA. (UNABLE TO GET DESIRED BUILD RATES WITH 1.5 DEGREE MOTOR). 22:30 - 00:00 1.50 DRILL P SURF BREAK OUT BIT AND SET ASIDE. ADJUST MUD MOTOR FROM 1.5 DEG TO 1.83 DEG. INSPECT OTHER BHA COMPONENTS. 10/30/2009 00:00 - 01:30 1.50 DRILL P SURF PJSM. CHANGE OUT TO NEW 12 -1/4" BIT. PU REMAINDER OF BHA; DIALED UP EXISTING MOTOR FROM 1.5 DEG TO 1.83 DEG, UBHO, JARS, AND RIH. WASH LAST STAND DOWN @ 550 GPM WITH 1400 PSI. NO FILL ON BOTTOM. 01:30 - 12:00 10.50 DRILL P SURF DRILL 12.250" SURFACE HOLE FROM 813' TO 1615', WITH 25K WOB, 600 GPM, 1640 PSI ON BOTTOM, 1530 PSI OFF BOTTOM, 60 RPM, 5.5K TORQUE ON BOTTOM, 2.5K TORQUE OFF BOTTOM. UP WT= 73K, DN WT.= 63K, RT WT= 66K. AST = 4.48 HRS, ART = 2.51 HRS, ADT = 6.99 HRS. RIG DOWN SPERRY SUN AND GYRO DATA @ 1096' NO FLUID LOST TO FORMATION IN PAST 12 HRS. 12:00 - 00:00 12.00 DRILL P SURF CONTINUE DRILLING 12.250" SI IRFAC:F HOI F FROM 1615' TO 3215'. WITH 25K WOB, 650 GPM, 2815 PSI ON BOTTOM, 2645 PSI OFF BOTTOM, 60 RPM, 7K TORQUE ON BOTTOM, 4.5K TORQUE OFF BOTTOM. UP WT= 90K, DN WT.= 65K, RT WT= 75K. AST = 2.30 HRS, ART = 6.20 HRS, ADT = 8.5 FIRS. 40 BBLS LOST TO FORMATION IN PAST 12 HRS. ENCOUNTERED HYDRATES @ 2090' 10/31/2009 00:00 - 01:00 1.00 DRILL P SURF DRILL 12.250" SURFACE HOLE FROM 3285' TO 3406', WITH 25K WOB, 650 GPM, 2715 PSI ON BOTTOM, 2650 PSI OFF BOTTOM, 60 RPM, 7K TORQUE ON BOTTOM, 4.5K TORQUE OFF BOTTOM. UP WT= 92K, DN WT.= 70K, RT WT= 77K. AST = .17 HRS, ART = .75 HRS, ADT = .92 HRS. 01:00 - 02:30 1.50 DRILL P SURF CIRCULATE 3X BOTTOMS UP, WITH 690 GPM @ 2800 PSI, SHAKERS CLEAN AFTER SECOND BOTTOMS UP. STILL SEEING SMALL AMOUNT OF HYDRATES AT BELL NIPPLE. MONITOR WELL, STATIC. 02:30 - 04:30 2.00 DRILL P SURF POH ON ELEVATORS FROM 3406' TO 215', WORKED THROUGH TIGHT AREA AT THE BASE OF PERMAFROST FROM 1980' -1870' NO OTHER PROBLEMS ENCOUNTERED ON TRIP OUT, HOLE TOOK PROPER DISPLAMENT. 04:30 - 06:30 2.00 DRILL P SURF STAND BACK THE 6 -3/4" MONEL DRILL COLLARS, LAY DOWN MWD BREAK BIT AND LAY DOWN MOTOR. 06:30 - 07:00 0.50 DRILL P SURF CLEAR AND CLEAN FLOOR OF ALL DIRECTIONAL TOOLS. 07:00 - 10:00 3.00 CASE P SURF MAKE DUMMY RUN WITH 9 -5/8" CASING HANGER. CHANGE OVER TO LONG BAILS RIG UP FRANKS TOOL, SLIPS, ELEVATORS AND POWER TONGS. 10:00 - 12:00 2.00 CASE P SURF PJSM, RUN 9 -5/8" 40# L -80 BTC SURFACE CASING TO 490', BAKER -LOCK SHOE TRACK, ENGAGE FRANKS TOOL, FILL PIPE AND CHECK FLOATS, OK. UTILIZE BEST -O -LIFE 2000 PIPE DOPE ON ALL CONNECTIONS, AVERAGE MAKE UP Printed: 11/30/2009 4:26:10 PM • BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/31/2009 10:00 - 12:00 2.00 CASE P SURF TORQUE = 7,900 FT /LBS. 12:00 - 15:00 3.00 CASE P SURF CONTINUE RUNNING 9 -5/8" 40# L-80 CASING PER RUNNING TALLY FROM 490' TO 1817', FILL CASING EVERY JOINT & BREAK CIRCULATION AND WASH DOWN EVERY 10 JOINTS. 15:00 - 15:30 0.50 CASE P SURF CIRCULATE BOTTOMS UP AT THE BASE OF THE PERMAFROST, 210 GPM @ 250 PSI. 15:30 - 18:30 3.00 CASE P SURF CONTINUE RUNNING 9 -5/8" 40# L -80 CASING PER RUNNING TALLY FROM 1817' TO 3396', MAKE UP LANDING JOINT AND CASING HANGER, LAND CASING. FILL CASING EVERY JOINT, BREAK CIRCULATION AND WASH DOWN EVERY 10 JOINTS. NO HOLE PROBLEMS ENCOUNTERED WHILE RUNNING CASING. LOST 11.5 BBLS TO FORMATION WHILE RUNNING CASING. RAN A TOTAL OF 83 JOINTS & 10' PUP JOINT. PLACED BOW SPRING CENTRALZERS ON JOINTS #1, #3 - #26 AND JOINTS #81 - #82. 18:30 - 19:00 0.50 CASE P SURF RIG DOWN FRANKS TOOL, BLOW DOWN TOP DRIVE, MAKE UP CROSSOVER AND CEMENT HEAD, RIG UP CIRCULATING LINES. 19:00 - 21:00 2.00 CASE P SURF BREAK CIRCULATION STAGE PUMPS UP TO 8 BPM ICP 600 PSI, FCP 430 PSI, RECIPROCATE PIPE IN 15' STOKES. UP WT = 145K, DN WT = 85K. CIRCULATE AND CONDITION MUD FOR CEMENT JOB. NO MUD LOST TO FORMATION DURING CIRCULATION. PUMPED A TOTAL OF 946 BBLS HELD PJSM WITH ALL RIG AND THIRD PARTY PERSONNEL. 21:00 - 00:00 3.00 CEMT P SURF PUMPED 5 BBL WATER AND TEST LINES TO 3,500 PSI, PUMPED 51 BBLS MUD -PUSH WEIGHTED TO 10.0 PPG, RELEASED BOTTOM PLUG AN) PI IMP 422 RRI S (YIFLD 4.51- 524 SX) ASL WEIGHTED TO 10.7 PPG @ 5 BPM ICP 125 PSI, FCP 475 PSI. (ADD 1 GAL DIE TO FIRST TUB or LEAD CEMENT) RECIPROCTE CASING 15' STROKES UP WT = 165K DN WT = 90K. WHILE PUMPING LEAD CEMENT. SHUT DOWN PUMPS AND BATCH TUB OF 15.8 PPG TAIL CEMENT, SUSPEND RECIPROCATION WHILE BATCHING UP TAIL CEMENT. PUMP 88 BBLS CLASS G TAIL CEMENT (YIELD 1.16 - 427 SX) WEIGHTED TO 15.8 PPG @ 5 BPM ICP 498 PSI. (AFTER BRING PUMPS BACK UP UNABLE TO RECIPROCATE PIPE PULLED UP TO 270K NO PIPE MOVEMENT.) RELEASED BOTTOM PLUG AND KICK OUT WITH 10 BBLS OF WATER FROM SCHLUMBERGER, CONFIRMED PLUG LEFT THE HEAD, SWITCH OVER TO THE RIG AND DISPLACE WITH RIG PUMPS AT 8 BPM ICP 283 PSI. (HAD TRACE OF MUD PUSH AT SHAKERS PRIOR TO DISPLACING WITH RIG PUMPS) CAUGHT UP WITH CEMENT 40 BBLS INTO DISPLACEMENT, SLOWED RATE TO 5 BPM @ 200 PSI. AT 80 BBLS INTO DISPLACEMENT (DEVELOPED A WASHOUT ON HIGH PRESSURE TEE ON THE CEMENT LINE. SHUT DOWN AND RIGGED UP SECONDARY HOSE FROM MUD MANIFOLD TO THE CEMENT HEAD PUMPS WERE DOWN FOR 15 MIN.) 11/1/2009 00:00 - 00:30 0.50 CEMT P SURF CONTINUE DISPLACING CEMENT WITH RIG PUMPS AT 5 Printed: 11/30/2009 4:26:10 PM • BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT _ Phase Description of Operations 11/1/2009 00:00 - 00:30 0.50 CEMT P SURF BPM WITH 200 PSI, CEMENTAT SHAKERS 196 BBLS INTO DISPLACEMENT, SLOWED RATE TO 3 BPM 10 BBLS PRIOR TO BUMPING PLUG. BUMPED PLUG WITH pALCULATED STROKES, TO 1500 PSI HELD FOR 5 MIN. BLED OFF AND CHECKED FLOATS. CIP © 00:30 HRS. 45 BBLS 10.7 PPG CEMENT RETURNED TO SURFACE. 00:30 - 01:30 1.00 CEMT P SURF FLUSH FLOW LINE RISER AND HYDRILL, BLOW DOWN CIRCULATING LINES. 01:30 - 02:00 0.50 BOPSUF P SURF BACK OUT AND LAY DOWN LANDING JOINT, RIG DOWN 350 TON ELEVATORS, CLEAR FLOOR OF ALL CASING EQUIPMENT. ** SET CLOCKS BACK 1 HR © 02:00 FOR DST. ** 02:00 - 04:30 2.50 BOPSUF P SURF NIPPLE DOWN 16" DIVERTER LINE. CLEAN OUT DRIP PAN UNDER ROTARY TABLE WITH SUPER SUCKER. SET ADDITIONAL MATS BEHIND CELLAR TO REMOVE 20" HYDRIL AND BRING IN WELL HEAD EQUIPMENT. 04:30 - 06:30 2.00 BOPSUF P SURF NIPPLE DOWN 20" RISER, HYDRIL AND DIVERTER SPOOL AND REMOVE FROM CELLAR. 06:30 - 09:00 2.50 WHSUR P SURF NIPPLE UP FMC 11" 5M CASING AND TUBING SPOOL. TEST M -M SEAL TO 1,000 PSI FOR 15 MIN. GOOD TEST. 09:00 - 12:00 3.00 BOPSUF P SURF NIPPLE UP BOP AND RISER, CONNECT TURN BUCKLES, AND INSTALL SECONDARY ANNULUS VALVES ON IA. 12:00 - 13:00 1.00 BOPSUF P SURF RIG UP BOP TEST EQUIPMENT, FILL STACK WITH WATER. 13:00 - 18:30 5.50 BOPSUF P SURF TEST BOPE TO 250 PSI LOW, 4,000 PSI HIGH WITH 3 -1/2" AND 4" TEST JOINTS, TEST ANNULAR TO 250 PSI LW' 2500 PSI HIGH, PER NABORS, BP AND AOGCC REGS. TEST WITTNESSED BY WSL MIKE DINGER, TOOLPUSHER CHRIS WEAVER AND AOGCC REP CHUCK SCHEAVE. 18:30 - 19:00 0.50 BOPSUF P SURF RIG DOWN BOP TEST EQUIPMENT, INSTALL WEAR BUSHING. 19:00 - 19:30 0.50 BOPSUF P SURF PJSM, CHANGE OVER TO SHORT BAILS AND PREPARE TO PICKUP DRILL PIPE. 19:30 - 20:30 1.00 DRILL P PROD1 PICKUP AND RACK BACK 15 JOINTS (5 STDS) 4" DP. 20:30 - 21:30 1.00 DRILL P PROD1 PICKUP 8 -3/4" DRILLING ASSEMBLY CONSISTING OF, HYCALOG DTX619M PDC BIT, MOTOR (1.15 DEG), ARC, MWD POWER PULSE, PICKED UP ADN TOOL HELD PJSM ON LOADING RADIOACTIVE SOURCE, ATTEMPTED T A O INSTALL SOURCE, SOURCE CAP STUCK IN TOOL, ATTEMPTS TO RETRIEVE CAP WERE UNSUCSESSFUL. 21:30 - 00:00 2.50 DRILL N SFAL PROD1 MWD ENGINEER CONTACTED FIELD FSM FOR ASSISTANCE, CONTINUE TROUBLE SHOOTING PROBLEM, SECURED SOURCE AND REMOVE FROM RIG FLOOR. LAY DOWN ADN TOOL. PROGRAM BACKUP ADN TOOL AND PICKUP. NEW SOURCE IS CURRENTLY BEING SHIPPED TO RIG FROM SHOP IN DEADHORSE. 11/2/2009 00:00 - 01:30 1.50 DRILL N SFAL PROD1 RADIOACTIVE SOURCE ARRIVED ON LOCATION © 01:00 HRS. LIFT SOURCE BOX TO FLOOR, HELD PJSM AND INSTALL SOURCE. 01:30 - 03:00 1.50 DRILL P PROD1 PICKUP REMAINING BHA CONSISTING OF, 2EA NMDC'S, NM STAB, NM, DC, XO JARS, CIRC SUB, XO, 20 JTS 4" HWDP, 14 JTS 4" DP, 8 -3/4" GHOST REAMER. SHALLOW TEST MWD © 822' Printed: 11/30/2009 4:26:10 PM • . BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/2/2009 03:00 - 06:00 3.00 DRILL P PROD1 RIH WITH 8 -3/4" DRILLING ASSEMBLY T/ 3,275' PICKING UP 4" DP FROM SHED. 06:00 - 07:00 1.00 DRILL P PROD1 BREAK CIRCULATION 168 GPM, 445 PSI, UP WT = 105K, DN WT = 55K. RIG UP HEAD PIN AND GAUGE AND TEST 9 -5/8 CASING TO 3,500 PSI FOR 30 MIN, RECORD ON CHART, GOOD TEST BLED OFF, R/D TEST EQUIPMENT. 07:00 - 09:00 2.00 DRILL P PROD1 CLEAN OUT CEMENT FROM 3275' TO 3314', DRILL FLOAT COLLAR AND CEMENT TO 3386', WOB = 5 -10K, 440 GPM, 1540 PSI, 40 RPM, 5.5K TORQUE, UP WT = 105K, DN WT = 57K, RT WT = 80K. 09:00 - 10:00 1.00 DRILL P PROD1 DISPLACE WELL OVER TO 8.8 PPG LSND MUD, PUMP 75 BBLS WATER, 50 BBL HIGH VIS SPACER, FOLLOWED BY 8.8 PPG LSND MUD AT 450 GPM, 950 PSI. 40 RPM, TORQUE = 4.5K 10:00 - 10:30 0.50 DRILL P PROD1 DRILL OUT REMAINING CEMENT AND SHOE, CLEAN OUT RAT HOLE TO 3406', DRILL 20' OF NEW HOLE TO 3426', 10K WOB, 575 GPM, 1450 PSI, 80 RPM, 5K TORQUE ART =.6HRS 10:30 - 11:00 0.50 DRILL P PROD1 CIRCULATE BOTTOMS UP @ 575 GPM, 1470 PSI 11:00 - 12:00 1.00 DRILL P PROD1 PULL UP INSIDE SHOE, RIG UP AND PERFORM LOT, MW IN & OUT = 8.9 PPG, TVD AT SHOE = 2876' PRESSURE ACHIEVED = 640 PSI.Elyla:3.2.P_PQ. RIG DOWN TEST EQUIPMENT. 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 8 -3/4" HOLE FROM 3426' TO 5430', 5 -20K WOB, 575 GPM, 2115 PSI ON BOTTOM, 2035 PSI OFF BOTTOM, 120 RPM, 9 -14K TORQUE ON BOTTOM, 7K S9 TORQUE OFF BOTTOM, UP WT = 130K, DN WT = 80K, RT WT = 97K. CAL ECD = 9.51, ACT ECD = 10.0. AST = 2.30 HRS, ART = 4.80 HRS, ADT = 7.1 HRS. 5 BBLS LOST TO FORMATION IN PAST 24 HRS. 11/3/2009 00:00 - 06:30 6.50 DRILL P PROD1 DIRECTIONAL DRILLED 8 -3/4" HOLE FROM 5430' TO 6280', 20 -25K WOB, 575 GPM, 2540 PSI ON BOTTOM, 2310 PSI OFF BOTTOM, 120 RPM, 9.5 K TORQUE ON BOTTOM, 7.5K TORQUE OFF BOTTOM, PU WT = 137K, SO WT = 85K, RT WT = 100K. CAL ECD = 9.51, ACT ECD = 10.22. 06:30 - 09:00 2.50 DRILL P PROD1 CIRCULATE & CONDITION 40 BBLS HI VIS / NUTPLUG SWEEP, 575 GPM, 2510 PSI, 120 RPM, 8K TQ, 105K RWT, PUMP TOTAL OF 2171 BBLS. 09:00 - 09:15 0.25 DRILL P PROD1 PJSM WITH RIG CREW ON POOH. 09:15 - 13:30 4.25 DRILL P PROD1 FLOW CHECKED WELL PRIOR TO PULLING OFF BOTTOM (STATIC). BACK REAMED OUT OF HOLE F/6340' T/5402', 575 GPM, 2450 PSI, 120 RPM, 6 -10K TQ, 95K RWT, 122K PUWT, 83K SOW. MAD PASS INTERVALS 6140' -6030' & 5850 -5650' AT 250 FPH WITH SAME PARAMETERS. 13:30 - 14:30 1.00 DRILL P PROD1 ATTEMPTED TO STRAIGHT POOH, BUT EXPERIENCED SWABBING AND 25K OVERPULL F/ DEPTHS 4522'- 4442', 4422'- 4344', 4324'- 4295', 4161'- 4143'. WORKED AND WIPED TIGHT AREAS, BUT STILL UNABLE TO STRAIGHT PULL PAST 4143'. 14:30 - 15:30 1.00 DRILL P PROD1 BACK REAMED F/ 4143' T/ 3396', 575 GPM, 2120 PSI, 120 RPM, 5K TQ. Printed: 11/30/2009 4:26:10 PM BP EXPLORATION Page 6 01 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/3/2009 15:30 - 17:00 1.50 DRILL P PROD1 CIRCULATED 750BBLS, 2020 PSI, 80 RPM, 4.5K TQ.CAL ECD =9.44, ACT ECD =9.69. 17:00 - 17:30 0.50 DRILL P PROD1 PJSM ON SLIPPING AND CUTTING DRILLING LINE. SLIPPED AND CUT A TOTAL OF 132' DL. 17:30 - 19:00 1.50 DRILL N WAIT PROD1 FOLLOW UP FROM RECENT SAFETY STAND -DOWNS WITH STEVE ROBINSON AND JEFF KILFOWLE. 19:00 - 19:30 0.50 DRILL P PROD1 RIG SERVICE - TOP DRIVE, DW'S, AND CROWN. 19:30 - 21:00 1.50 DRILL P PROD1 POOH F/ 3305' T /300' RACKING BACK DP AND HWDP IN DERRICK. FLOW CHECKED WELL (STATIC). 21:00 - 21:15 0.25 DRILL P PROD1 PJSM ON LAYING DOWN BHA. 21:15 - 23:00 1.75 DRILL P PROD1 LD DIRECTIONAL BHA, SLB REMOVED & SECURED RA SOURCE. CLEANED RIG FLOOR AND PULL WEAR BUSHING. 23:00 - 23:15 0.25 BOPSUF P RUNPRD PJSM WITH RIG CREW ON CHANGING BOP RAMS. 23:15 - 00:00 0.75 BOPSUF P RUNPRD CHANGED TOP RAMS TO 7" CASING RAMS. 11/4/2009 00:00 - 01:00 1.00 BOPSUF P RUNPRD INSTALLED 7" TOP PIPE RAMS AND PRESSURE TESTED 250 / 4000 PSI WITH 7" TEST JOINT. 01:00 - 01:15 0.25 CASE P RUNPRD PJSM WITH RIG CREW ON RIGGING (JP CASING RUNNING TOOLS. 01:15 - 04:30 3.25 CASE P RUNPRD RIG UP CASING RUNNING TOOLS. MAKE A DUMMY RUN WITH MANDREL HANGER. 04:30 - 11:00 6.50 CASE P RUNPRD HOLD A PJSM WITH THE NABORS CASING CREW, NABORS RIG CREW, NABORS TOURPUSHER, AND BP WSL. MAKE UP THE FLOAT EQUIPMENT AND RUN IN THE HOLE WITH SHOE TRACT. CHECK THE FLOATS. HELD. RUN 7" ,BTC -M, 26 #, L -80 CASING TO A DEPTH OF 1176' WITH AN AVERAGE TORQUE OF 8600 FT /LBS. CONTINUE IN THE HOLE WITH 7" TC -II, 26 #, L -80 CASING FROM 1176' TO 3372' WITH AN AVERAGE TORQUE OF 10,100 FT /LBS. CIRCULATE AND ESTABLISH PICK UP/ SLACK OFF WTS EVERY 10 JTS. PICK UP WT. 96K / DOWN WT. 78K. 11:00 - 12:00 1.00 CASE P RUNPRD CIRCULATE 1.5X THE CASING VOLUME OF 194 BBLS STAGING PUMP UP TO 5 BPM WITH 285 PSI. 12:00 - 17:30 5.50 CASE P RUNPRD CONTINUE IN THE HOLE WITH 7" TC -II, 26 #, L -80 CASING FROM 3372' TO 6340' WITH AN AVERAGE TORQUE OF 10,100 FT /LBS. CIRCULATE AND ESTABLISH PICK UP/ SLACK OFF WTS EVERY 10 JTS. PICK UP WT. 175K / DOWN WT. 110K. 17:30 - 20:30 3.00 CEMT P RUNPRD BEGIN CIRCULATING AT .5BPM WITH 300 PSI. BEGIN STAGING PUMP UP TO A FINAL CIRCULATING RATE OF 6 BPM WITH 450 PSI. 20:30 - 21:00 0.50 CEMT N CEMT RUNPRD DUE TO COMPRESSIVE STRENGTH ONLY BEING AT 820 PSI AT 23:30 HOURS INTO THE TEST, THE TOWN ENGINEER WAS CALLED TO VERIFY THE PUMPING OF THE CEMENT. IT WAS DECIDED THAT THE CEMENT COULD BE PUMPED AFTER TALKING WITH THE ENGINEER TEAM LEAD. 21:00 - 22:30 1.50 CEMT P RUNPRD CEMENT 7" CASING AS FOLLOWS. BEGAN BY PUMPING 5 BBLS OF 11 PPG MUD PUSH AND PRESSURE TESTED SCHLUMBERGER LINES TO 4500 PSI. GOOD TEST. CONTINUED TO PUMP AN ADDITIONAL 45 BBLS OF 11 PPG MUD PUSH AT 5 BPM WITH 545 PSI. DROPPED THE BOTTOM PLUG AND PUMPED IT OUT WITH 61 BBLS (315 Printed: 11/30/2009 4:26:10 PM • • BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2009 21:00 - 22:30 1.50 CEMT P RUNPRD SACKS) OF 15.8 PPG CLASS "G" CEMENT WITH A YIELD, OF 1.17 CUBIC FT / SACK AT 5 BBU MIN WITH 760 PSI ICP. AFTER 61 BBLS AWAY FCP OF 1100 PSI AT 1 BBU MIN. DROPPED THE TOP PLUG. DISPLACED THE CEMENT WITH 240 BBLS OF 9.0 PPG BRINE AT AN INITIAL CIRCULATING RATE OF 6 BBUMIN. WITH 230 PSI AND A FINAL CIRCULATING RATF OF 1 BRI /MIN WITH 9R5 PSI BUMPED THE PLUG AT 4083 STROKES. BLED OFF THE PRESSURE TO CHECK FOR FLOW. NO FLOW. RECIPROCATED THE PIPE 15' TO 20' THROUGHOUT THE ENTIRE CEMENT JOB. 22:301- 23:00 0.50 CEMT P RUNPRD PRESSURE UP TO 4000 PSI TO TEST THE CASING FOR 30 MINUTES. GOOD TEST. 23:00 - 00:00 1.00 CEMT P RUNPRD RIG DOWN CEMENTIING HEAD AND LINES. PULL AND LAY DOWN 7" LANDING JOINT. RIG DOWN CASING RUNNING TOOLS. 11/5/2009 00:00 - 00:30 0.50 CEMT P RUNPRD RIG DOWN CASING RUNNING TOOLS. CLEAR AND CLEAN FLOOR. 00:30 - 01:30 1.00 WHSUR P OTHCMP INSTALL FMC 7" MANDREL HANGER PACK -OFF AND TEST TO 5000 PSI FOR 30 MINUTES. 01:30 - 02:30 1.00 BOPSUF P OTHCMP INJECT 15 BBL DRILLING MUD DOWN 9 5/8" X 7" OA AT 1 BPM AT 585 PSI 02:30 - 03:30 1.00 BOPSUF P OTHCMP CHANGE TOP RAMS FROM 7" TO VARIABLE. 03:30 - 05:30 2.00 BOPSUF P OTHCMP TEST VBR RAMS WITH 3 1/2" AND 4" TEST JOINTS TO 250 PSI AND 4000 PSI 05:30 - 13:00 7.50 PERFOB N CEMT OTHCMP WAIT ON CEMENT. LAB TEST CONFIRMS THAT CEMENT WILL ATTAIN 1000 PSI COMPRESSIVE STRENGTH AFTER 31 HOURS AND 28 MINUTES. LOADING 3 1/2" TUBING INTO PIPE SHED. DRIFT AND STRAP TUBING IN PREPARATION FOR COMPLETION. WORK THROUGHOUT THE RIG WHILE WAITING ON COMPRESSIVE STRENGTH. CUT EXCESS LINE OFF OF THE DRILLER SIDE TUGGER, CHANGE OUT THE BRIDGE CRANE CABLE AND OFF DRILLER SIDE HANGING ARM. CLEAN THE PITS, AND SCRUB THROUGHOUT THE RIG. INJECT 5 MORE BBL DRILLING MUD DOWN 9 5/8" X 7" OA AT 1 BPM WITH 720 PSI. CONTINUE TO INJECT AT 1 BBL EVERY HOUR UNTIL CEMENT REACHED 500 PSI COMPRESSIVE STRENGTH. 13:00 - 15:00 2.00 PERFOB P OTHCMP INJECT A TOTAL OF 67 BBLS OF 9.0 PPG MUD DOWN 9 5/8" X 7" OA AT 1 BPM WITH 800 PSI, FOLLOWED BY 29 BBLS OF 15.2 PPG MUD AT 2 BPM WITH 750 PSI. RIG UP LITTLE RED SERVICES AND PRESSURE TEST LINES TO 3000 PSI. GOOD TEST. INJECT 67 BBLS OF DEAD CRUDE AT 3 BPM WITH 600 PSI TO ENSURE THAT THE ANNULUS WAS OPEN. ALL IN/JCTION WAS DONE DOWN 9 5/8" X 7" OA. 15:00 - 16:30 1.50 PERFOB N CEMT OTHCMP LOAD THE SHED WITH THE PERFORATING GUNS AND RIG UP THE HANDLING EQUIPMENT. STILL WAITING ON CEMENT TO REACH 1000 PSI COMPRESSIVE STRENGTH. Printed: 11/30/2009 4:26:10 PM • • BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2009 16:30 - 17:00 0.50 PERFOB N DPRB OTHCMP PRESSURE TEST THE 7" CASING TO 4000 PSI FOR 30 MINUTES. TEST LOST A TOTAL OF 60 PSI. 30 PSI IN THE FIRST 15 MINUTES AND 30 PSI IN THE SECOND 15 MINUTES. 17:00 - 19:00 2.00 PERFOB N WAIT OTHCMP WAIT ON SCHLUMBERGER PERFORATING CREW TO CHANGE OUT A MIS - LOADED GUN. 19:00 - 21:00 2.00 PERFOB P OTHCMP PRESSURE TEST THE 7" CASING TO 4000 PSI FOR 30 MINUTES. TEST LOST A TOTAL OF 20 PSI. 15 PSI IN THE FIRST 15 MINUTES AND 5 PSI IN THE SECOND 15 MINUTES. GOOD TEST. CONTACTED THE TOWN ODE TO VERIFY NORMAL OPERATIONS COULD RESUME DUE TO THE CASING TEST AND THE CEMENT COMPRESSIVE STRENGTH. 21:00 - 00:00 3.00 PERFOB P OTHCMP PJSM WITH SCHLUMBERGER PERFORATING CREW, BP WSL, NABORS TOURPUSHER, NABORS RIG CREW, AND SCHLUMBERGER MWD HAND. PICK UP 4 1/2" TCP PERFORATING GUNS, 5 SPF 4505PJ WITH eFIRING SYSTEM. RUN IN THE HOLE ON 4" DRILL PIPE FROM THE DERRICK TO 1000'. SHALLOW TEST LWD. 11/6/2009 00:00 - 02:30 2.50 PERFOB P OTHCMP CONTINUE RIH WITH TCP GUNS ON DRILLL PIPE FROM DERRICK. TAG AT 6243' ON 7" FLOAT COLLAR. 02:30 - 04:30 2.00 PERFOB P OTHCMP CONNECT TOP DRIVE. CIRCULATE TO START LWD TOOLS. LOG WITH LWD SENSOR READING FROM 5806' TO 5649' TO COVER TOP OF OA FORMATION AT 5682'. LOG UP AT 300' /HR. PUMP AT 230 GPM, 780 PSI TO ACQUIRE 2 SAMPLE POINTS PER FOOT (DATA DENSITY) FOR GR. REPEAT LOGING PASS TO CONFIRM FORMATION TIE -IN. NOTE: LOCATE "RA" TAG IN 7" CASING PUP JOINT AT 5652' ON GR LOG 04:30 - 05:30 1.00 PERFOB P OTHCMP PLACE GUNS ON DEPTH WITH TOP SHOT AT 5682' AND BOTTOM SHOT AT 6068' FIRE TCP GUNS WITH eFIRE PRESSURE SEQUENCE. GOOD SURFACE INDICATION THAT GUNS FIRED. IMMEDIATE LOSS OF 11 BBL BRINE PERFORATE INTERVALS: 5682' - 5742' 60' .. (.% 5788' - 5838' 50' 5860' - 5872' 12' r 5916' - 5940' 24' 5996' - 6068' 72' POH TO POSITIION PERF GUNS ABOVE TOP PERF. 05:30 - 06:00 0.50 PERFOB P OTHCMP PULL OUT OF THE HOLE TO 5569'. SHUT DOWN AND MONITOR THE WELL FOR 10 MINUTES. LOSSES OF 11 ti BPH. BLOW DOWN THE TOP DRIVE AND KILL LINE. 06:00 - 07:00 1.00 PERFOB P OTHCMP CIRCULATE 202 BBLS AT 250 GPM WITH 750 PSI. MONITOR THE WELL FOR 10 MINUTES. LQS9ES OF 11 BPH. 07:00 - 09:00 2.00 PERFOB P OTHCMP PULL OUT OF THE HOLE FROM 5569' TO 2716' LAYING Printed: 11/30/2009 4:26:10 PM • BP EXPLORATION Page 9 of 11'` Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/6/2009 07:00 - 09:00 2.00 PERFOB P OTHCMP DOWN THE DRILL PIPE. 09:00 - 09:30 0.50 PERFOB P OTHCMP RUN IN THE HOLE TO 3862' WITH THE REMAINDER OF THE DRILL PIPE FROM THE DERRICK. 09:30 - 11:30 2.00 PERFOB P OTHCMP PULL OUT OF THE HOLE FROM 3862' TO 458' LAYING DOWN THE DRILL PIPE. 11:30 - 14:30 3.00 PERFOB P OTHCMP MONITOR THE WELL FOR 10 MINUTES. LOSSES OF 12 BPH. PULL OUT OF THE HOLE FROM 458' LAYING DOWN THE PERFORATING GUNS. CONFIRM THAT ALL SHOTS FIRED. RIG DOWN AND CLEAR THE RIG FLOOR OF ALL SCHLUMBERGER PERFORATING TOOLS AND HANDLING EQUIPMENT. 14:30 - 15:30 1.00 EVAL P OTHCMP SPOT AND RIG UP THE E -LINE UNIT AND PREPARE TO RUN GAUGE RINGS AND LOG THE WELL. 15:30 - 17:30 2.00 EVAL P OTHCMP RUN IN THE HOLE WITH A 5.99" GAUGE RING AND JUNK BASKET TO 6215'. JUNK BASKET CONTAINED A SMALL AMOUNT OF GUN DEBRIS AND CEMENT. 17:30 - 19:00 1.50 EVAL P OTHCMP RUN IN THE HOLE WITH A 6.125" GAUGE RING AND JUNK BASKET TO 6012'. JUNK BASKET CONTAINED A SMALL AMOUNT OF GUN DEBRIS. 19:00 - 20:30 1.50 EVAL P OTHCMP RUN IN THE HOLE WITH A 6.11" GAUGE RING AND JUNK BASKET TO 6206'. JUNK BASKET CONTAINED A SMALL AMOUNT OF GUN DEBRIS AND CEMENT. 20:30 - 23:00 2.50 EVAL P OTHCMP RUN IN THE HOLE WITH A 6.125" GAUGE RING AND JUNK BASKET TO 6014'. JUNK BASKET CONTAINED MINIMAL DEBRIS. 23:00 - 23:30 0.50 EVAL P OTHCMP RIG UP TO RUN THE USIT ON THE WELLBORE. 23:30 - 00:00 0.50 EVAL P OTHCMP BEGIN RUNNING IN HOLE TO PERFORM A USIT LOG ON THE WELLBORE. 11/7/2009 00:00 - 05:00 5.00 EVAL P OTHCMP RUN USIT CEMENT EVALUATION LOG IN HIGH RESb UTION (5 dea -1,5 ") FROM 6200' TO 5100', WHIICH IS ABOVE THE TOP OF THE OA SAND AT 5682' SECOND USIT RUN IN NORMAL MODE (5 deg -6 ") FROM 6200' TO SURFACE. _TOP OF CEMENT AT 4250'. GOOD QUALITY CEMENT BEHIND CASING_ RIG DOWN LOGGING UNIT. BRINE LOST TO WELL FROM MIDNIGHT 7 BBL 05:00 - 08:00 3.00 RUNCOMP RUNCMP RIG UP TO RUN 3 1/2" COMPLETION. RIG UP HYDRAULIC POWER TONGS AND TORQUE TURN COMPUTER. RIG UP I WIRE SPOOLER. MAKE A DUMMY RUN WITH THE TUBING HANGER. 08:00 - 12:00 4.00 RUNCOMP RUNCMP MAKE UP 3.5" L -80 9.2# TC -II COMPLETION EQUIPMENT AND RUN IN THE HOLE TO 250'. AVERAGE TORQUE OF 2300 FT /LBS. BAKERLOK ALL COMPLETION EQUIPMENT BELOW THE BOTTOM PACKER. UTLIZING JET LUBE SEAL GUARD ON ALL TUBING JOINTS. COMPLETION CONSISTS OF THE FOLLOWING: - 3.5" WLEG - 3.5" XN NIPPLE - 3.5" X NIPPLE - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH - 3.5" X NIPPLE Printed: 11/30/2009 4:26:10 PM • • BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/7/2009 08:00 - 12:00 4.00 RUNCOMP RUNCMP - 1 JOINT 3.5" L -80 9.2# TC -II - NDPG - 3.5" X 7" BAKER PREMIER PORTED PACKER - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH 12:00 - 00:00 12.00 RUNCOMP RUNCMP CONTINUE TO MAKE UP 3.5" L -80 9.2# TC -II COMPLETION EQUIPMENT AND RUN IN THE HOLE FROM 250' - 4267'. AVERAGE TORQUE OF 2300 FT /LBS. UTLIZING JET LUBE SEAL GUARD ON ALL TUBING JOINTS. UP WT. 55K DOWN WT. 47K COMPLETION CONSISTS OF THE FOLLOWING: - NDPG - 3.5" X 7" BAKER PREMIER PORTED PACKER - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH - NDPG - 3.5" X 7" BAKER PREMIER PORTED PACKER - 1 JOINT 3.5" L -80 9.2# TC -II - 1 PUP JOINT 3.5" L -80 9.2# TC -II - 3.5" X 1.5" MMG -W GLM W/ RD DUMMY - RK LATCH - NDPG - 3.5" X 7" BAKER PREMIER PORTED PACKER - 3.5" X NIPPLE - 3.5" X 1.5" MMG GLM W/ DCR -1 SHEAR VALVE - RK LATCH - 1 JOINT 3.5" L -80 9.2# TC -II W/ RA TAG - 89 JOINTS 3.5" L -80 9.2# TC -II - 3.5" X NIPPLE - 125 JOINTS 3.5" L -80 9.2# TC -II BRINE LOST TO WELL LAST 24 HOURS 11 BBL 11/8/2009 00:00 - 03:30 3.50 RUNCOMP RUNCMP CONTINUE TO MAKE UP 3.5" L -80 9.2# TC -II COMPLETION EQUIPMENT AND RUN IN THE HOLE TO 6107'. AVERAGE TORQUE OF 2300 FT /LBS. UTLIZING JET LUBE SEAL GUARD ON ALL TUBING JOINTS. UP WT. 75K / DOWN WT. 57K COMPLETION CONSISTS OF THE FOLLOWING: - 54 JOINTS 3.5" L -80 9.2# TC -II - 2 PUP JOINTS 3.5" L -80 9.2# TC -II - 1 JOINT 3.5" L -80 9.2# TC -II -3.5" X 4.5" CROSSOVER PUP JOINT - FMC HANGER WITH 4.5" TC -II LIFTING THREADS 03:30 - 04:30 1.00 RUNCOMP RUNCMP SPACE OUT TUBING WITH WLEG AT 6137' CLEAR FLOOR FOR ELINE TEST I WIRE. 04:30 - 05:30 1.00 RUNCOMP RUNCMP RIG UP SCHLUMBERGER ELINE LOGGING UNIT. 05:30 - 08:00 2.50 RUNCOMP RUNCMP RUN CCUGR TOOLS TO CORRELATE TUBING DEPTH. TIE IN WITH RA TAG IN 7" CASING AND GR. 08:00 - 09:30 1.50 RUNCOMP RUNCMP ADD A 5" PUP TO THE COMPLETION SI DING. MAKE UP FMC 11" X 4 1/2" TUBING HANGER. TERMINATE I WIRE THROUGH TUBING HANGER. TEST I WIRE. LAND TUBING ON TUBING HANGER WITH WLEG AT 6143' Printed: 11/30/2009 4:26:10 PM • • BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: L -222 Common Well Name: L -222 Spud Date: 10/29/2009 Event Name: DRILL +COMPLETE Start: 10/26/2009 End: 11/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 11/8/2009 09:30 - 12:00 2.50 RUNCOMP RUNCMP DROP BALL AND ROD TO XN NIPPLE WITH HCR SEAT AT 6121' PRESSURE UP TO 4200 PSI TO SET PACKERS. BLEED PRESSURE TO 4000 PSI. HOLD FOR 30 MINUTES TO TEST TUBING. BLEED PRESSURE TO 1500 PSI. PRESSURE UP ANNILUS TO 4000 PSI AND HOLD FOR 30 MINUTES TO TEST IA. BLEED IA AND TUBING TO 0 PSI. PRESSURE UP IA AND SHEAR DCR VALVE IN GLM AT 5592 WITH XX PSI CIRCULATE 2 BBL EACH WAY TO CONFIRM DCR OPEN. 12:00 - 13:30 1.50 BOPSUF P RUNCMP INSTALL TWC VALVE IN TUBING HANGER, TEST WITH 1000 PSI FROM BELOW. 13:30 - 15:00 1.50 BOPSUF P RUNCMP NIPPLE DOWN BOP. NIPPLE DOWN FLOW LINE AND RISER. 15:00 - 19:00 4.00 WHSUR P RUNCMP NIPPLE UP DOUBLE MASTER VALVE DRY HOLE TREE AND ADAPTOR SPOOL. PASS I WIRE THROUGH ADAPTOR SPOOL AND TERMINATE. TEST I WIRE. PRESSURE TEST TUBING HANGER AND ADAPTOR SPOOL TO 5000 PSI FOR 30 MINUTES. TEST TREE TO 5000 PSI WITH DIESEL. 19:00 - 20:00 1.00 WHSUR P RUNCMP INSTALL LUBRICATOR ON TREE AND TEST TO 500 PSI. PULL TWC VALVE. RIG DOWN LUBRICATOR. 20:00 - 21:00 1.00 WHSUR P RUNCMP REVERSE CIRCULATE 112 BBL INHIBITED 9.0 PPG BRINE INTO IA AT 3 BPM WITH 490 PSI. 21:00 - 23:00 2.00 WHSUR P RUNCMP RIG UP LITTLE RED SERVICES. TEST LINES TO 3000 PSI. REVERSE CIRCULATE 84 BBL 80 DEG F DIESEL DOWN IA AT 3 BPM WITH 650 PSI. ALLOW TO U TUBE TO FREEZE PROTECT THE TUBING AND IA TO 2388' (2200' TVD). 23:00 - 00:00 1.00 WHSUR P RUNCMP RIG UP LUBRICATOR ON TREE AND TEST. INSTALL BPV AND TEST TO 1000 PSI WITH LITTLE RED SERVICES. RIG DOWN LUBRICATOR. INSTALL VR PLUGS IN IA OUTLETS AND OA OUTLET. SECURE WELL BLOW DOWN LINES. RELEASE RIG AT 24:00 HRS SUNDAY 8 NOVEMBER 2009 Printed: 11/30/2009 4:26:10 PM by 0 L -222 Survey Report Schlumberger Report Date: 4- Nov -09 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 80.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: L -PAD / L -222 TVD Reference Datum: Rotary Table Well: L -222 TVD Reference Elevation: 79.10 ft relative to MSL Borehole: L -222 Sea Bed / Ground Level Elevation: 50.50 ft relative to MSL UWIIAPI #: 500292342000 Magnetic Declination: 22,166° Survey Name 1 Date: L -222 / November 4, 2009 Total Field Strength: 57658.062 nT Tort / AHD 1 DDI 1 ERD ratio: 104.150 / 3660.91 ft / 5.698 / 0.755 Magnetic Dip: 80.897° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 30, 2009 Location LatlLong: N 70 21 2.872, W 14919 21.962 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 5978343.990 ftUS, E 583412.290 ftUS North Reference: True North Grid Convergence Angle: +0.63780013 Total Corr Mag North •> True North: +22.166 • Grid Scale Factor: 0.99990790 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) I (ft) (ft) (ft ) (ft ) (ft ) (ft ) (ft ) (degl100ft ) (ftUS) (ftUS) _ RTE 0.00 0.00 0.00 -79.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978343.99 583412.29 N 70 21 2.872 W 149 19 21.962 GYD GC SS 78.00 0.04 140.09 -1.10 78.00 0.01 0.03 0.03 -0.02 0.02 0.05 5978343.97 583412.31 N 70 21 2.872 W 149 19 21.962 180.00 0.34 85.52 100.90 180.00 0.33 0.35 0.34 -0.02 0.34 0.31 5978343.97 583412.63 N 70 21 2.872 W 149 19 21.952 269.00 0.66 84.25 189.90 269.00 1.11 1.13 1.12 0.05 1.12 0.36 5978344.05 583413.40 N 70 21 2.872 W 149 19 21.930 359.00 1.08 68.49 279.89 358.99 2.45 2.49 2.45 0.41 2.42 0.53 5978344.43 583414.71 N 70 21 2.876 W 149 19 21.892 445.00 1.41 64.70 365.86 444.96 4.27 4.36 4.29 1.16 4.13 0.40 5978345.20 583416.41 N 70 21 2.883 W 149 19 21.842 538.00 2.00 70.13 458.82 537.92 6.97 7.12 7.04 2.20 6.69 0.66 5978346.26 583418.96 N 70 21 2.894 W 149 19 21.767 629.00 2.66 74.84 549.75 628.85 10.64 10.82 10.74 3.29 10.22 0.75 5978347.40 583422.47 N 70 21 2.904 W 149 19 21.664 718.00 3.83 78.54 638.60 717.70 15.67 15.86 15.76 4.42 15.13 1.33 5978348.58 583427.37 N 70 21 2.915 W 149 19 21.520 814.00 5.45 84.44 734.29 813.39 23.42 23.62 23.46 5.50 22.81 1.76 5978349.74 583435.04 N 70 21 2.926 W 149 19 21.296 904.00 8.27 85.45 823.63 902.73 34.13 34.36 34.13 6.43 33.52 3.14 5978350.79 583445.73 N 70 21 2.935 W 149 19 20.983 1000.00 12.64 83.75 918.02 997.12 51.49 51.78 51.49 8.12 50.85 4.56 5978352.68 583463.04 N 70 21 2.952 W 149 19 20.476 MWD +IFR +MS 1026.95 14.12 86.47 944.23 1023.33 57.70 58.01 57.71 8.64 57.06 5.97 5978353.27 583469.25 N 70 21 2.957 W 149 19 20 1120.55 19.66 86.75 1033.76 1112.86 84.70 85.20 84.82 10.24 84.20 5.92 5978355.17 583496.36 N 70 21 2.973 W 149 19 19 1215.85 22.72 84.92 1122.61 1201.71 118.96 119.64 119.23 12.78 118.55 3.28 5978358.09 583530.67 N 70 21 2.998 W 149 19 18. 1310.25 24.83 83.73 1208.99 1288.09 156.91 157.69 157.28 16.56 156.41 2.29 5978362.29 583568.49 N 70 21 3.035 W 149 19 17.391 1405.27 27.24 79.75 1294.37 1373.47 198.57 199.38 198.94 22.61 197.65 3.13 5978368.80 583609.66 N 70 21 3.094 W 149 19 16.186 1499.79 29.82 79.87 1377.41 1456.51 243.71 244.52 244.00 30.59 242.08 2.73 5978377.27 583653.99 N 70 21 3.173 W 149 19 14.888 1595.79 28.62 80.20 1461.19 1540.29 290.58 291.38 290.82 38.71 288.23 1.26 5978385.90 583700.05 N 70 21 3.253 W 149 19 13.539 1690.17 27.82 80.53 1544.35 1623.45 335.20 336.01 335.43 46.18 332.23 0.86 5978393.86 583743.96 N 70 21 3.326 W 149 19 12.253 i 1786.97 29.28 79.74 1629.38 1708.48 381.46 382.27 381.66 54.11 377.81 1.56 5978402.30 583789.44 N 70 21 3.404 W 149 19 10.921 1881.67 32.09 80.42 1710.81 1789.91 429.79 430.60 429.96 62.42 425.41 2.99 5978411.14 583836.94 N 70 21 3.486 W 149 19 9.530 1977.19 34.70 81.28 1790.55 1869.65 482.35 483.17 482.53 70.77 477.31 2.78 5978420.06 583888.74 N 70 21 3.568 W 149 19 8.013 2072.21 36.36 79.71 1867.88 1946.98 537.56 538.38 537.73 79.90 531.76 1.99 5978429.80 583943.08 N 70 21 3.658 W 149 19 6.421 2165.40 39.00 79.68 1941.63 2020.73 594.52 595.34 594.67 90.09 587.80 2.83 5978440.61 583999.00 N 70 21 3.758 W 149 19 4.784 SurveyEditor Ver SP 2.1 Bld( users) L- 222 \L - 222 \L - 222 \L -222 Generated 11/30/2009 2:24 PM Page 1 of 3 Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub•Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft) (ft) (ft) (ft) (ft ) (ft ) (ft ) (deg/100ft ) (ftUS) (ftUS) _ 2262.24 40.59 78.96 2016.03 2095.13 656.49 657.32 656.61 101.58 648.71 1.71 5978452.78 584059.76 N 70 21 3.871 W 149 19 3.004 2356.58 42.95 80.02 2086.39 2165.49 719.33 720.16 719.43 113.03 710.49 2.61 5978464.91 584121.41 N 70 21 3.983 W 149 19 1.198 2451.98 44.27 80.77 2155.46 2234.56 785.12 785.96 785.22 124.01 775.37 1.49 5978476.61 584186.16 N 70 21 4.091 W 149 18 59.302 2548.62 45.94 82.13 2223.67 2302.77 853.56 854.41 853.68 134.17 843.07 1.99 5978487.52 584253.73 N 70 21 4.191 W 149 18 57.323 2644.24 45.63 80.91 2290.35 2369.45 922.06 922.94 922.20 144.28 910.85 0.97 5978498.38 584321.39 N 70 21 4.290 W 149 18 55.342 2738.97 47.92 81.41 2355.23 2434.33 991.07 991.97 991.22 154.88 979.05 2.45 5978509.74 584389.46 N 70 21 4.395 W 149 18 53.349 2834.90 47.17 80.02 2419.98 2499.08 1061.84 1062.74 1062.00 166.29 1048.90 1.32 5978521.93 584459.17 N 70 21 4.507 W 149 18 51.307 2930.37 48.66 77.48 2483.97 2563.07 1132.66 1133.59 1132.79 180.13 1118.37 2.52 5978536.54 584528.48 N 70 21 4.643 W 149 18 49.277 3025.49 47.84 77.71 2547.31 2626.41 1203.56 1204.55 1203.64 195.38 1187.68 0.88 5978552.55 584597.61 N 70 21 4.793 W 149 18 47.251 3120.71 47.00 77.67 2611.74 2690.84 1273.62 1274.66 1273.67 210.32 1256.18 0.88 5978568.26 584665.93 N 70 21 4.939 W 149 18 45.249 3216.46 47.22 79.40 2676.91 2756.01 1343.74 1344.81 1343.78 224.26 1324.93 1.34 5978582.97 584734.52 N 70 21 5.076 W 149 18 43.240 3311.10 48.16 81.72 2740.62 2819.72 1413.72 1414.80 1413.75 235.73 1393.96 2.07 5978595.20 584803.41 N 70 21 5.189 W 149 18 41. 3338.27 47.95 81.49 2758.78 2837.88 1433.92 1435.01 1433.96 238.68 1413.95 1.00 5978598.37 584823.37 N 70 21 5.218 W 149 18 40 3433.03 46.70 80.73 2823.01 2902.11 1503.57 1504.67 1503.62 249.44 1482.78 1.44 5978609.90 584892.07 N 70 21 5.324 W 149 18 38. 3531.27 44.57 82.61 2891.70 2970.80 1573.76 1574.90 1573.83 259.64 1552.26 2.56 5978620.86 584961.42 N 70 21 5.424 W 149 18 36.596 3623.44 46.59 82.95 2956.21 3035.31 1639.51 1640.72 1639.60 267.91 1617.57 2.21 5978629.86 585026.62 N 70 21 5.505 W 149 18 34.687 3718.45 48.53 83.65 3020.32 3099.42 1709.51 1710.84 1709.64 276.08 1687.20 2.11 5978638.81 585096.15 N 70 21 5.585 W 149 18 32.652 3809.81 49.84 82.45 3080.04 3159.14 1778.55 1779.98 1778.72 284.45 1755.83 1.74 5978647.94 585164.68 N 70 21 5.668 W 149 18 30.646 3905.76 48.38 82.90 3142.84 3221.94 1851.00 1852.51 1851.22 293.70 1827.77 1.56 5978657.99 585236.51 N 70 21 5.758 W 149 18 28.543 3999.54 49.96 82.66 3204.16 3283.26 1921.88 1923.47 1922.14 302.62 1898.16 1.70 5978667.69 585306.79 N 70 21 5.846 W 149 18 26.486 4093.82 50.00 81.53 3264.78 3343.88 1994.03 1995.67 1994.32 312.55 1969.68 0.92 5978678.42 585378.18 N 70 21 5.943 W 149 18 24.396 4189.14 49.37 82.45 3326.46 3405.56 2066.66 2068.35 2066.99 322.68 2041.65 0.99 5978689.35 585450.03 N 70 21 6.043 W 149 18 22.292 4283.10 48.43 82.93 3388.22 3467.32 2137.39 2139.15 2137.77 331.70 2111.88 1.07 5978699.14 585520.14 N 70 21 6.131 W 149 18 20.240 4378.23 48.65 80.81 3451.21 3530.31 2208.64 2210.44 2209.04 341.78 2182.44 1.69 5978710.01 585590.59 N 70 21 6.230 W 149 18 18.177 4474.41 49.72 78.35 3514.08 3593.18 2281.41 2283.23 2281.80 354.95 2254.02 2.23 5978723.98 585662.01 N 70 21 6.360 W 149 18 16.085 4570.08 48.80 79.27 3576.52 3655.62 2353.88 2355.71 2354.23 369.02 2325.13 1.21 5978738.84 585732.95 N 70 21 6.498 W 149 18 14.007 4665.82 49.58 79.18 3639.09 3718.19 2426.34 2428.17 2426.66 382.57 2396.31 0.82 5978753.17 585803.97 N 70 21 6.631 W 149 18 11.926 4760.48 48.77 78.61 3700.97 3780.07 2497.96 2499.80 2498.24 396.37 2466.60 0.97 5978767.75 585874.09 N 70 21 6.766 W 149 18 9.872 4855.97 49.97 76.84 3763.16 3842.26 2570.36 2572.27 2570.60 411.78 2537.41 1.89 5978783.95 585944.72 N 70 21 6.918 W 149 18 7.802 4951.25 48.81 76.95 3825.17 3904.27 2642.59 2644.60 2642.77 428.18 2607.85 1.22 5978801.13 586014.97 N 70 21 7.079 W 149 18 5.743 5046.02 48.54 76.87 3887.75 3966.85 2713.65 2715.77 2713.79 444.30 2677.17 0.29 5978818.02 586084.10 N 70 21 7.237 W 149 18 3� 5140.25 48.54 77.92 3950.14 4029.24 2784.20 2786.39 2784.30 459.71 2746.09 0.84 5978834.20 586152.83 N 70 21 7.388 W 149 18 1. 5235.95 47.84 78.37 4013.94 4093.04 2855.49 2857.72 2855.57 474.37 2815.90 0.81 5978849.63 586222.47 N 70 21 7.532 W 149 17 59.662 5331.67 48.31 78.44 4077.90 4157.00 2926.68 2928.94 2926.75 488.68 2885.66 0.49 5978864.71 586292.06 N 70 21 7.673 W 149 17 57.623 5428.16 50.06 77.10 4140.96 4220.06 2999.64 3001.96 2999.69 504.16 2957.02 2.10 5978880.98 586363.24 N 70 21 7.825 W 149 17 55.537 5523.88 49.30 76.89 4202.90 4282.00 3072.52 3074.94 3072.55 520.58 3028.13 0.81 5978898.20 586434.15 N 70 21 7.986 W 149 17 53.458 5618.33 48.41 77.09 4265.04 4344.14 3143.55 3146.06 3143.56 536.60 3097.43 0.96 5978914.98 586503.26 N 70 21 8.143 W 149 17 51.433 5714.49 48.24 79.31 4328.99 4408.09 3215.33 3217.88 3215.34 551.28 3167.73 1.73 5978930.45 586573.39 N 70 21 8.287 W 149 17 49.378 5809.95 47.29 81.40 4393.16 4472.26 3286.00 3288.56 3286.01 563.13 3237.40 1.90 5978943.07 586642.91 N 70 21 8.403 W 149 17 47.342 5905.81 46.70 81.32 4458.54 4537.64 3356.08 3358.66 3356.09 573.66 3306.70 0.62 5978954.37 586712.09 N 70 21 8.507 W 149 17 45.316 6000.27 46.11 80.45 4523.67 4602.77 3424.48 3427.07 3424.50 584.50 3374.25 0.91 5978965.95 586779.50 N 70 21 8.613 W 149 17 43.342 6095.98 43.85 82.46 4591.37 4670.47 3492.10 3494.71 3492.12 594.57 3441.13 2.79 5978976.77 586846.27 N 70 21 8.712 W 149 17 41.386 SurveyEditor Ver SP 2.1 Bld( users) L- 222 \L - 222 \L - 222 \L -222 Generated 11/30/2009 2:24 PM Page 2 of 3 • Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft) (deg) (deg) (ft) _ (ft) _ (ft) _ (ft) (ft) (ft ) (ft ) (deg /100ft ) (ftUS) (ftUS) 6191.09 42.99 82.49 4660.45 4739.55 3557.41 3560.09 3557.45 603.13 3505.94 0.90 5978986.05 586910.97 N 70 21 8.796 W 149 17 39.492 Last Survey 6277.58 42.46 81.89 4723.99 4803.09 3616.05 3618.77 3616.09 611.11 3564.08 0.77 5978994.67 586969.01 N 70 21 8.874 W 149 17 37.793 TD (Projected) 6340.00 42.46 81.89 4770.04 4849.14 3658.17 3660.91 3658.21 617.05 3605.80 0.00 5979001.08 587010.66 N 70 21 8.932 W 149 17 36.573 Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - ( In -field referenced MWD with mutt- station analysis and correction applied in post - processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Survey Error Model: BP ISCWSA version 10 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From ( ft) MD To ( ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 30.10 Act -Stns BP_GYD SS -Depth Only L -222 -> L- 222 30.10 1000.00 Act -Stns BP_GYD SS L -222 -> L -222 1000.00 3338.27 Act -Stns BP_MWD +IFR +MS^ ^1 L -222 -> L -222 3338.27 6277.58 Act -Stns BP_MWD +IFR +MS^A2 L -222 -> L -222 • 6277.58 6340.00 Act -Stns BP BLIND L -222 -> L -222 Legal Description: Northing (Y) IftUSI Easting (X) IftUSI Surface : 2619 FSL 3501 FEL S34 T12N R11E UM 5978343.99 583412.29 BHL : 3236 FSL 5174 FEL S35 T12N R11E UM 5979001.08 587010.66 • SurveyEditor Ver SP 2.1 Bld( users) L- 222 \L - 222 \L - 222 \L -222 Generated 11/30/2009 2:24 PM Page 3 of 3 TREE = 4" CM/ WELLHEAD = FMC - SOTES: ACTUATOR = LEO L-222 KB. ELEV = 78.6' BF. ELEV = 48.1' L I KOP Max A ngle = = 50° @ 5428' 400' 26' 1 X 3-1/2" XO, ID = 2.992" I 20" CONDUCTOR 106' 2806' H 3-1/2" HES X NIP, ID = 2.813" I Datum MD = 5820' 91.5 #, A -53, Datum TVD = 4400" SS ID = 19.124" 9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H 3396' 1 4250' H ESTIMATED TOC IN 7" LNR I 7" CSG, 26 #, L -80 TCII XO TO L -80 BTC H 5154' 1 — X GAS LIFT MANDRELS I3 -1/2" MARKERJOINTw/ RA TAG H 5553' 1 t STI MD TVDI DEV TYPE VLV !LATCH PORTI DATE Minimum ID = 2.75 " @ 6121' 8 5593 4327 49 MMG DCR -1 RKP 0 11/08/09 3 -1/2" HES XN NIPPLE I I 56 13' -- 13 -1/2" HESXNIP, ID= 2.813" 17" X 3 -1/2" BKR PREM PORTED PKR, ID = 2.875" H 5633' F — ] 5650' H 3 -1/2" NDPG MULTI - SENSOR SUB, ID = 2.992" I 17' MARKER JOINT w / RA TAG H 5649' F--t WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 5670 4379 48 MMG -W DMY RK 0 11/08/09 6 5739 4425 48 MMG -W DMY RK 0 11/08/09 5 5793 4461 47 MMG -W DMY RK 0 11/08/09 4 5832 4487 47 MMG -W DMY RK 0 11/08/09 3 5899 4553 47 MMG -W DMY RK 0 11/08/09 2 5940 4561 47 MMG -W DMY RK 0 11/08/09 ' 1 6082 4660 44 MMG -W DMY RK 0 11/08/09 17" X 3 -1/2" BKR PREM PORTED PKR, ID = 2.875" H 5764' I-g 5753' H 3 -1 /2" HES X NIP, ID = 2.813" ■ I 5776' 1 NDPG MULTI - SENSOR SUB, ID = 2.992" I 5851' H 7" X 3 -1/2" BKR PREM PORTED PKR, ID = 2.875" 1 5868' H 3 -1/2" NDPG MULTI - SENSOR SUB, ID = 2.992" I 5888' H 3 -1/2" HES X NIP, ID = 2.813" I PERFORATION SUMMARY REF LOG: USIT ON 11/17/09 g 5969' H 7" X 3-1/2" BKR PREM PORTED PKR, ID = 2.875" ANGLE ATTOPPERF: N/A 5986' 3 - 1/2" NDPG SINGLE - SENSOR SUB, ID = 2.992" Note: Refer to Production DB for historical perf data 1 I� SIZE SPF ZONE INTERVAL Opn /Sqz DATE 4-1/2" 5 OA 5679 - 5739 0 11/06/09 1 6051' H 3-1/2" HES X NIP, ID = 2.813" 4 -1/2" 5 OBa 5 - 58 0 11/06/09 4 -1/2" 5 OBb 5857 869 0 11/06/09 4 -1/2" 5 OBc 5 59 0 11/06/09 ' ' 1 6100' H 3 -1/2" HES X NIP, ID = 2.813" 4 -1/2" 5 OBd 5993 - 6065 0 11/06/09 1 6121' 1 HES XN NIP, ID = 2.750" I 13 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 6142' I/ • 1 6144' I - - 1/2" WLEG, ID = 2.992" I ( PBTD H 6243' �� 1 H ELMD NOT LOGGED I 17" CSG, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" 1 - 1 6330' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 11/08/09 N7ES ORIGINAL COMPLETION WELL: L -222 11/19/09 TW /PJC FINAL DRLG CORRECTIONS PERMIT No: x 2091190 API No: 50- 029 - 23420 -00 SEC 34, T12N, R11 E, 2369' FSL & 1522' FWL BP Exploration (Alaska) . i N0.5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambol' Shoat, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2935 Attn: Christine Mahnken ATTN: Beth 1 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date BL Color CD OWOW -SW B38O.00032 RST/WFL C! • - _Xi r '" • ' 11/07/09 1 1 L -223 8581.00014 USIT ii Yzici1L_Lli�1.l' 10121 I: 1 1 8 -218 BSJN -00018 0,1.140 iriiri.:L> >L TA11111111111111111111111 10/21/09 1 1 i 0380-00031 tl ali lairaie 'S;ligILlliliLlYir • 11107109 1 1 13f4B -00079 10/31109 1 1 8148.00078 I a . 10130109 1 1 L1-14 18 A AW H-00077 RST "�i�Q�� 12 - r a 10/30109 1 1 18 8148.00077 RST �,, 0-288 AX8000053 MCNL " a, ., 10102/09 1 1 9-2213 881(5-00008 - ST •$ 10/27/09 1 1 0-24 AWL8-00035 - =T :. —44' - 09/27/09 1 1 18 -15B AYS4-00107 - = T j — f_ ' _ `, 0 10131/09 1 1 L2 -07A MO -00047 - - _ 6 l j0 1 10/29/09 1 1 OWDWSW 838040032 GFfiMIOvlT.T VFAIII T•L'k 11/07/09 1 12-05AP81 40015441 OH MWO/LWO E ' 1T Awjr`aiYsXewri'y, 07/0/107 1 06 -218 08AKAO016 OH MWD/LWO EDIT a 2f -(• " t 07/29/08 1 0 -15A 09AKA0175 OH MWdLWD EDIT _ 4 5 -Q _ _ 09/07/09 1 L -223 09AKA0081 OH MWD/LWD EDIT t 1 1 ' — (� Q . 10/10109 1 L -223 8581. 00014 CH EDIT PDC SIT _.4 j,, _ • ' d i & • , 10/21/09 1 S -218 85JN -00018 CH EDIT PDC USIT i , ail - •r 1 10121/09 1 L -222 0380.00031 ' '! • 1 r V � . • ••• • , • • 11/07109 1 04.33A 09AKA0075 OH MWD/LWD EDIT _ .; _ • • , - , , 09!19109 2 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2.1 2525 Gambell Street. Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 // 4 , ii SlihnithergeP NO. 5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job It Log Description Date BL Color CD OWDW -SW 8380 -00032 RST/WFL C- • a ' a 11/07/09 1 1 S -228 0581-00014 USIT - Q _ ( a' I a 10/21/09 1 1 S-218 B5JN-00018 _ 7 .. 8 USIT (} &� � IS ,i t 10/21/09 1 1 L -222 B3SO -00031 USIT i „ • - a A la • 11/07/09 1 1 12 -24 6148 -00079 CalllirtallircnenralMra a 10/31109 1 1 12 -32 8148 -00078 r L /Y-1 10/30/09 1 1 _ 11-14 AVIH -00029 i. a 10/27/09 1 1 L2 -18A 614B -00077 RST j , !' 10/30/09 1 1 D -28B AXBD -00053 MCNL a 111 .q ! / - 0 1 10/02109 1 1 S -22B B8K5 -00008 RSTJJ - LC 1 A' . — 1 / 9(19 '3- 10/27/09 1 1 D -24 AWL8-00038 RST - - ' ; 09/27/09 1 1 18 -15B AYS4 -00107 RST y - IIC • . ' 10/31/09 1 1 04 -21 ANHY -00115 HOME_ ai I ff 0 10/27/09 1 1 L2-07A AY00 -00047 a: -- 10/29/09 1 1 OWDW -SW 63S0 -00032 (��nT j lX#r � Tj�K 11/07/09 ! 1 12- 05APB1 40015441 OH MWD/LWD EDIT ./41j�: , Jti 07/01/07 2 1 06 -218 08AKA0016 OH MWD/LWD EDIT d , -- a 41: . 07/28/08 2 1 D -16A 09AKA0175 OH MWD/LWD EDIT _AM ; - VIEW. I_' 09/07/09 2 1 L -223 j. a�j 09AKA00 CH EDIT �� a n O 10/10/09 2 . 1 L -223 8581 -00014 14 EDIT PD (US CH EDIT PDC (USIT) (1�(' _ 09 4 � Q41C)15 41C)15 3 10/21/09 1 S -218 B5JN -00018 CH EDIT PDC (USIT) ( rjr, ACA - cA q /IP ■ - 10/21/09 1 L -222 8350 -00031 CH EDIT PDC (USIT) , e1 -- 01 ; • . 11/07/09 -- 1 04-33A 09AKA0075 OH MWD /LWD EDIT a C 01 -Only 1,- /9 ' 09/19/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 • • f T� Z 0 -// MECHANICAL INTEGRITY REPORT - FUD DATE: /0/2 VO OPER fi FIELD ( Or 10 RIG RsLEr2C. • /0/:2497 WELL NUMBER , L'ZZZ' DATA MD LL DA._ 4 TD s .3� TVD Casing: 7 Shoe: MD - ice •T_V'D CPg Liner: Shoe: MD 'TVD; TOP: HD T V 0?- _cbing: -,, Packer MX TVD; Set at - . 33 •"• Bole Size and ; Perfa to MEC?JJ CAL INTEGRITY - PART # 1 • Annulus Press Test: IP "firifo 15 min ; 30 min. Comments- 5/a0o p s 7 1f} ic" 3° .4�-�, . ��• MECHANICAL INTEGRITY - PART #2 Class 4. °3 ) Ssx- C ement Volumes: Amt. Liner to (L'f Gag ; DV , Cmt vol to cover perfs ° ... Theoretical IOC ? o p/ q , Q -, qqao ( Mb Cement Bond Log Olor No) L(.T/ / ; In AOGCC File • � rr CBL Evaluation, tone above perfs . Production Log: Type t Evaluation • 'CONCLUSIONS: 1 : Va' 7. e s s J I I J � ‘-e- 0e- • m9-9 ?art # 2 : /2/6 -e9 • 1 0:714 r. ( v i A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Prudhoe Bay Field, Orion Schrader Bluff L -222 BP Exploration (Alaska), Inc. Permit No: 209 -119 Surface Location: 2620' FSL, 3501' FEL, Sec. 34, T12N, R11E, UM Bottomhole Location: 3248' FSL, 123' FWL, Sec. 35, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, a - Daniel T. Seamount, Jr. Chair 7 DATED this g day of October, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA tY � ALAS• IL AND GAS CONSERVATION COMMI� N EEI�/E D PERMIT TO DRILL OCT 0 6 2009 20 AAC 25.005 la. Type of work: 1 b. Proposed Well Class: ❑ Development Oil ❑ Service - Winj ❑ Single Zone LL'f , p ; • • n ® Drill ❑ Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone 4 a •4; " = .-$ • AlTIZEZT ❑ Re -Entry ❑ Exploratory ® Service - WAG ❑ Service - Disp ' nchtmesit le Gas ., 2. Operator Name: 5. Bond: IN Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU L -222 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 6387' TVD 4885' Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Schrader Bluff Surface: ADL 028239 & 028238 2620' FSL, 3501' FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3166' FSL, 356' FEL, SEC. 34, T12N, R11 E, UM October 25, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3248' FSL, 123' FWL, SEC. 35, T12N, R11 E, UM 2560 7,350' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: Plan 79' feet 15. Distance to Nearest Well Open Surface: x- 583412 y- 5978344 Zone- ASP4 GL Elevation above MSL: 50.5' feet to Same Pool: 344' 16. Deviated Wells: Kickoff Depth: 400' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 49 degrees Downhole: 2180 Surface: 1699 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 129.45# X -65 Weld 80' Surface Surface 108' 108' —260 sx Arctic Set 12 -1/4" 9 -5/8" 40# L -80 BTC 3407 Surface Surface 3407' 2878' 510 sx Arcticset Lite. 409 sx Class 'G' 8 -3/4" 7" 26# L -80 TC -II 4907' Surface Surface 4907' 3862' (See Below) 8 -3/4" 7" 26# L -80 BTC -M 1.480 , 4907' 3862' 6387' 4885' 65 sx LiteCrete. 182 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): ' Junk (measured): Casing Length Size Cement Volume MD TVD Conductor / Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: ❑ Property Plat ❑ BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Zach Sayers, 564 -5790 Printed Name Robert Tirpacck Title Engineering Team Leader Prepared By Name/Number Signatur Phone 564 -4166 Date A /7 Terrie Hubble, 564 -4628 Commission Use Only Permit To Drill API Number: Permit Appr I a : See cover letter for Number: v2®9JJ9 50- l,?�9o?J1 00000 i 0 � 0 1 other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Le Other q000 psi, i;90 P eSt % Samples Req'd: ❑ xes Ise No Mud Log Req'd: ❑ , Yes ErNo .0 2500 ps'' /) n n u.l ar^ / eS H J H Measures: Yes ❑ No Directional Survey Req'd: lta f Yes ❑ No — L(, l 4 - � t o peg. '7 ; 0'+ ; et a. cc.orI w/ AR) Z6 A ,tlI e h a p rod GI - Pga(d/ 4. re etec.epf' ' E /0 , 2, 5.033(J)J L- APPROVED BY THE COMMISSION "" . Lyn . G a a Date el F7 -� , COMMISSIONER Form 10-401 Revised( /2009 / This permit is valid for 24 months from the date of ap • oval (20 AAC 25.005(g)) Submit n Duplicate ' ORiENAL by • 0 L -222i Permit to Drill Application Well: L -2221 ' Well Injector Target Schrader Type: Objective: API Number: TBD Estimated Spud Date: October 25 2009 Prepared By , Zach Sayers Rig: Nabors 7ES GL: 50.5' RTE: 79' Surface Northing, Easting Offsets TRS Location 5,978,344 583,413 2,620' FSL / 3,501' FEL 12N, 11E, 34 Target Northing Fasting TVDss Offsets TRS Locations 5,978,925 586,550 4,310' 3,165' FSL / 356' FEL 12N, 11E, 34 Bottom Northing Easting TVDss Offsets TRS Location 5,979,013 587,028 4,807' 3,248' FSL / 5,157' FEL 12N, 11E, 35 Planned KOP: 400' MD / Planned TD: 6,387 MD / 323' TVDss 4,807' TVDss DIRECTIONAL - PLAN #2B Maximum Hole Angle: 49° in the 8 -3/4" section Close Approach Wells: Reference AC report in directional plan Survey Program: MWD Standard + IIFR / MS Nearest Property Line: 7,350' South of PBU Boundary Nearest Well within Pool: L -103 — 344' from L -222i WP #2b @ OBf_Base Contacts: Name: Phone: Email: Drilling Engineer Zach Sayers (907) 564 -5790 Zach.Sayers@bp.com Geologist Joe Turak (907) 564 -4204 Joseph.Turak@bp.com Production Engineer Taylor West (907) 564 -4647 Taylor.West c bp.com L -222i Permit To Drill Page 1 WELLS WITHIN 1 /4 Mil OF THIS INJECTION WELL. Casing. Well: Interval 0 Top of roc Meth Used to Determine T © Name Top Schrader _ Schrader " f /amiler-adius 7" Injection 5,242' 4,560' Based on USIT ran 8/6/02 L -103i MD MD Notes: 4,560' MD (Ugnu UG3) 5 -'h" 5,463' 5,050' Calculated TOC assuming 30% excess L -120 Production MD MD Notes: I 5,050' MD (Ugnu UG1) 7" 5,354' 4 MD MD L -03 I ntermediate MD MD Calculated TOC assuming 30% excess Notes: ] 4,800' MD (Ugnu UG3) 7-%" 5,276' MD 4,420' Calculated TOC assuming 30% excess L -204 Intermediate MD Notes : I 4,420' MD (Ugnu UG3) 7-%" 5,379' 4,450' Calculated TOC assuming 30% excess L -201 Intermediate MD MD Notes: [ 4,450' MD (Ugnu UG3) i t L -222i Permit To Drill Page 2 • FORMATION MARKS L -2221 (BASED ON SOR) Est:. Commercial Estimated Formation Forma Uncerta Hydrocarbon Bearing Pore Pressure (TVDss) (feet) (Yes/No) (Psi) (ppg EAi1W) G1 750' +/- 50' no 115 8.65 Fault #1 (L Pad Fault) 860' +/- 150' M.D. SV6 1,350' +/- 50' no 387 8.65 EOCU 1,485' +/- 50' no 608 8.65 SV5 1,620' +/- 50' no 668 8.65 SV4 1,690' +/ - 50' Gas hydrates below BPRF 729 8.65 BPRF 1,975' +/ 50' - 761 8.65 SV3 2,150' +/ - 50' Gas hydrates 889 8.65 SV2 2,485' +/ - 50' Gas hydrates 968 8.65 SV1 2,790' +/ - 50' Gas hydrates 1,118 8.65 UG4 2,800' +/- 50' 1,256 8.65 UG4A 2,810' +/- 50' Heavy Oil 2,820' - 2,890' SS 1,265 8.65 UG3 3,170' +/ - 50' Thin coals 1,427 8.65 UG1 3,705' +/- 50' Heavy Oil 3,690' - 3,760' SS 1,667 8.65 Fault #2 3,895' +/- 150' M.D. UG_Ma (faulted top) 3,895' +/- 50' Heavy oil 1,753 8.65 UG_Mb1 3,920' +/- 50' Heavy oil 1,764 8.65 UG_Mb2 3,995' +/- 50' Heavy oil 1,798 8.65 UG_Mc 4,080' +/- 50' No - wet 1,836 8.65 SB_Na 4,150' +/- 25' No - wet 1,868 8.65 SB_Nb 1 4,175' +/- 25' No - wet 1,880 8.66 SB_Nc 4,210' +/- 25' No - wet 1,900 8.68 SB_Ne 4,220' +/- 25' No - wet 1,920 8.75 SB 4,310' +/- 25' Oil 1,900 8.48 SB_OBa 4,390' +/- 25' Oil 1,355 5.94 SB_OBb 4,435' +/- 25' Oil 1,480 6.42 SB_OBc 4,495' +/- 25' Oil 2,000 8.56 SB_OBd 4,550' +/- 25' Oil 1,810 7.65 SB 4,625' +/- 25' Oil 2,090 8.69 SB_OBf 4,675' +/- 25' Oil 2,110 8.68 Base_SB_OBf 4,730' +/- 25' No 2,130 8.66 TD 4,813' No f 2,180 8.71 L -222i Permit To Drill Page 3 CASING/TUBING PRItRAM • Size Csg / OD Wt / Ft Grade Conn. Burst Collapse. a Le ` MDIT Dr kb MD/TV!) rlcfa g (psi) (psi) 42" 20" 129.45# X -65 WELD 2,473 1,500 80' GL 108'/108' 12 -1/4" 9 -%" 40# L -80 BTC 5,750 3,090 3,407' GL 3,407' / 2,878' 8 - 7" 26# L -80 TC -II 7,240 5,410 4,907' GL 4,907' / 3,862' 8 - /d' 7" 26# L -80 BTC -M 7,240 5,410 1,480' 4,907' / 3,862' 6,387' / 4,885' Tubing 3 - 9.2# L -80 TC -II 10,160 10,540 6,387' GL 6,387' / 4,885' MUD PROGRAM Surface Hole Mud Properties: DrilPlex (Freshwater Mud) 12 - '1/4" Hole Section Depth Internal Density (pP9) PV YP API FL PH GL - Base Perm 8.5 — 9.2 ALAP 50 — 90 NC 10.8 — 11.2 Base Perm — UG4 9.0 -9.5 6 -14 50 -90 NC 10.8 -11.2 Injection Hole Mud Properties: LSND Fluid (Freshwater Mud) 8 - 3 /4" Hole Section Depth Interval, ." Density (ppg) PV YP API FL PH MBT Csg Shoe — TD 8.6 -9.4 8 -14 18 -24 <6.0 9 -10 <15 LOGGING PROGRAM 12 -1/4" Surface: 9 -%" Casing Drilling: Dir /GR SURF — 9-%" Shoe Open Hole: None Cased Hale: None 8 - Injection : 7" Casing Dir /GR /Res /Neu/ Drilling: Azimuthal Den 9-%" Shoe — TD Open Hole: None Cased Hole: USIT L -222i Permit To Drill Page 4 CEMENT PROGRAM* • 9 -%" Surface Casing Section Casing Size 9-%" 40 #, L -80 BTC Lead: Open hole volume with 250% excess in permafrost, and 40% excess below permafrost Port collar used at 1,000' MD if necessary Basics: Lead TOC: Surface Tail: Open hole volume with 40% excess, and 80' shoe track Tail TOC: 1,000' above 9 -%" shoe Spacer 50 bbls of Viscous Spacer weighted to 10.0 ppg (Mud Push II) Total Cement; Lead 410 bbls, 2,300 ft 510 sks, 4.51 ft /sk, 10.7 lb/gal ASL Volume: Tail 84 bbls, 474 ft 409 sks, 1.16 ft /sk, 15.8 lb/gal Class G Temp BHST = 40° F (from SOR) 7" Injection Casing Section Casing Size 7" 26 #, L -80 BTC -M x TC -II Lead: Open hole volume with 30% excess Basks Lead TOC: 1,000' MD below Surface Casing Shoe Tail: Open hole volume with 30% excess, and 80' shoe track Tail TOC: 500' above the Top of the MA sandstone Spacer 50 bbls of Viscous Spacer weighted to 10.0 lb/gal (Mud Push 11) Total Cement Lead 34.1 bbls, 192 ft3, 65 sks, 2.94 ft /sk, 11.5 lb/gal LiteCrete + adds Volume: Tail 38 bbls, 213 ft 182 sks, 1.17 ft /sk, 15.8 lb/gal Class G + Latex Temp BHST = 85° F (from SOR) SURFACE SHUT -IN WELLS At surface L -219i to the West is required to be shut before Nabors 9ES rig can be moved on to the well. Wellhead L -219i is 30' from center to the West from L -2221. The well house will need to be removed. HYDROGEN SULFIDE Recent H data from the pad is as follows: Well Name HS Level (ppm) Date of Reading #1 Closest SHL Well H Level L -2191 N/A #2 Closest SHL Well H Level L -120 200 9/12/2008 #1 Closest BHL Well H Level L -204 10 7/15/2008 #2 Closest BHL Well H Level L -201 20 12/3/2007 Max. Recorded H on Pad/Facility L -120 250 10/20/2006 Other Relevant H Data All L Pad production wells have H2S in the range from 10 - (H alarms from rigs, etc.) 250 ppm as a result of using IPA gas lift gas. L -222i Permit To Drill Page 5 • WELL CONTROL The 12 -1/4" surface hole will be drilled with a 16" diverter. The 8 -3/4' injection hole will use well control equipment consisting of 5,000 psi working pressure pipe rams 2 , blind /shear rams, and an annular preventer will be 9 P 9 i P PP O P installed and is capable of handling the maximum potential surface pressures. Annular preventer will be tested to 2,500 psi. Based upon calculations below, BOP equipment will be tested to 4,000 psi. BOP regular test frequency will be 14 days with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 8 - /a" Injection Interval Maximum Anticipated SHP.. 2,180 psi 0 4,813' TVD, 8.7 ppg EMW Mazirrmm Surface Pressure 1,699 psi (.10 psi /ft gas gradient to surface) (SB_OBf) Kick Tolerance 76.7 bbl with a 12.0 ppg FIT /LOT Planned BOP Test Pressure Rams test to 4,000 psi /250 psi. Annular test to 2,500 psi /250 psi 9 Casing Test 3,500 psi surface pressure integrity Test -846" Hole LOT after drilling 20' — 50' of new hole : Planner! Completion Fluids ; 9.0 ppg Seawater / 6.8 ppg Diesel VARIANCE REQUESTS: To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole to a depth of 1,000' MD. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. DISPOSAL: • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul all Class I waste to Pad 3 for disposal. L -222i Permit To Drill Page 6 Drillirt Hazards and Continancies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be normally pressured from 5.9 to 8.7 ppg EMW. II. Lost Circulation/Breathing A. Risks of lost circulation for the proposed L - 222i Schrader well are low. III. Kick Tolerance/Integrity Testing 8 - Injection Interval Maximum Anticipated BHP 2,180 psi @ 4,813' TVD, 8.7 ppg EMW Maximum Surface Pressure 1,699 psi (.10 psi /ft gas gradient to surface) (SB_OBf) Kick Tolerance 76.7 bbl with a 12.0 ppg FIT /LOT Planned BOP Test Pressure Rams test to 4,000 psi /250 psi. Annular test to 2 500 si /250 psi P p 9 -%" Casing Test - 3,500 psi surface pressure Integrity Test `8 -V4" Hole : LOT after drilling 20' — 50' of new hole Planned Completion Fluids 9.0 ppg Seawater / 6.8 ppg Diesel IV. Heavy Oil A. Heavy oil is expected in the UG4A and UG1 sand intervals, which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones; depths of heavy oil intervals are outlines in the Marker Tops section. VI. Hydrogen Sulfide Recent H data from the pad is as follows: Well Name H Level (ppm) Date of Reading #1 Closest SHL Well H Level L -219i N/A #2 Closest SHL Well H Level L -120 200 9/12/2008 #1 Closest BHL Well H Level L -204 10 7/15/2008 #2 Closest BHL Well H Level L -201 20 12/3/2007 Max. Recorded H on Pad /Facility L -120 250 10/20/2006 Other Relevant H Data All L Pad production wells have H2S in the range from 10 - (H alarms from rigs, etc.) 250 ppm as a result of using IPA gas lift gas. VII. Faults Formation Where MD TVDSS Est. Vertical. Fault Throw Direction Uncertainty Encoun .Fault Intersect Intersect Offset to #1 SV6 i 830' 750' 10' - 40' Di West he +/ -150' MD Comments: Penetrated by nearly all wells drilled from L Pad with no losses Dips to the UG1 5,076' 3,895' 150' — 180' West +/ -100' MD Comments: j Intersection is at high angle to avoid paralleling fault VIII. Anti - Collision Issues A. Reference Anti - collision report in directional plan CONSULT THE L -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L -222i Permit To Drill Page 7 L -222i - LTrill and Complete Procedureeummary Pre -Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Remove nearby well house. Rig Operations: 1. MIRU Nabors 7ES. 2. Nipple up and function test diverter. 3. MU 12 -3/4" drilling assembly with MWD /GR and directionally drill surface hole to TD. The surface hole TD will be in the UG4. 4. Run and cement 9-%", 40 #, BTC, L -80 surface casing. A TAM port collar may be run at 1,000' as a contingency. Pressure test casing to 3,500 psi for 5 minutes at plug bump. 5. ND diverter and NU casing / tubing head. NU BOPE and test to 4,000psi. 6. Make up 8 -3/4" drilling BHA with MWD /GR /RES /Azi- Den /NEU /PWD and RIH to float collar. Pressure test casing (& Annulus valves) to 3,500 psi for 30 minutes. Drill out shoe track and displace well to LSND drilling fluid. Drill 20' of new formation and perform LOT. 7. Drill ahead to injection interval target TD. Circulate one BU, then POOH on elevators to run casing. 8. Run and cement the 7" casing. Displace with 9.0 ppg seawater. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. 9. Install and test 9-%" x 7" pack -off. 10. Freeze protect the 9-%" x 7 "annulus. 11. Space out perf guns by utilizing GR and LWD log. PU DPC guns and RIH with 4 -'h" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR for gun correlation. 12. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, OBc, and OBd. POOH. LD DP and guns. 13. RU Schlumberger E -line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 14. Run all. log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 15. Run the 3 -1 ", 9.2# completion with a 7" x 3 -1/2" straddle packer assembly, I -wire, gauges, and injection mandrels. Torque Turn TC -II threaded tubing. Space out packers using E -line and USIT. 16. Run in lockdown screws, drop ball & rod, and set the packers. Give AOGCC 24 hours notice, then test tubing to 4,000 psi for 30 minutes. Bleed off to 2,000 psi and pressure up the IA to 4,000 psi and hold for 30 minutes. Bleed off all pressures. 17. Shear the DCR valve and pump both ways to confirm circulation ability. 18. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5,000 psi. 19. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 20. Install BPV in tubing hanger. Install all annulus valves and secure the well. Ensure that IA/OA are protected with two barriers. 21. RDMO Post -Rig Work: 1. Install tree with electric SSV actuator. 2. MIRU slick -line. Pull the ball and rod / RHC plug. 3. Pull shear valve from top mandrel and replace with a dummy GLV. 4. Pull dummy valves from injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install well house and flow lines. L -222i Permit To Drill Page 8 TREE = 4 -1/16" CW SAFETY NOTES: *** HES PKR @ 6341' IS "PULL TO CAN BE RELEASED BY PRESSURE. DO ACTUA OR = l3ectr Props e d L-2221 SI BUT 2 PSSI TES OF ES RATING I } B. ELEV 78.6' (4332 80% )*** BF. ELEV = 48.1' KOP= 400' 1 L ) 1 I 27' H4 - 1/2" X 3 - 1/2" XO, ID = 2.992 " Max Angle' = 48.99° @2611' Datum MD = , ' 1 2,500' H3 HES X NIP, ID = 2.813" I Datum TV D = 120" CONDUCTOR H 108' i GAS LIFT MANDRELS H S8T 1MD TVD I DEV I TYPE 1 VLV I LATCH PORT DATE I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" I I 3,407' 17" CSG, 26 #, L - 80 TCII XO TO L - 80 BTC - M 1-1 4,767' WATER INJECTION MANDRELS Minimum ID = 2.75" @ 6,146' MI ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 MMG -W 3 -1/2" HES XN NIPPLE 6 MMG -W 5 MMG -W 4 MMG -W 1 3 MMG -W I3 - 1/2" HES X NIP, ID = 2.813" I 5,641' 2 MMG - 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" H 5,663' � ,= 1 Z. ** MMG -W 13 -1/2" RA PIP TAG H 5,632' ** INSIDEX NIPPLE 1 MARKER JOINT w /RA PIP TAG H 5,672' M1 1 M1 5,677' 1H3 - 1/2" NDPG MULTI SENSOR SUB , ID = 2.992 I 17" X 3 -1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" H I � 5,782' I ' ' 5,771' I— I3 -112" HES X NIP, ID = 2.813" I M ' 5,796' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I I 17" X 3 -1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" IH 5,867' I —g MI 1 1 5,880' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I PERFORATION SUMMARY REF LOG: SLB REALTIME LWD ON 04/18/08 1 I 5,900' I-13 -1/2" HES X NIP, ID = 2.813" I ANGLE AT TOP PERF: 42 ° @ 6442' Mr I Note: Refer to Production DB for historical pert data �1 SIZE SPF ZONE INTERVAL Opn /Sqz DATE 5,995' H7" X 3 -1/2" DUAL FEEDTHRU PKR, ID = 2.965" I 4 - 1/2" 5 OA i I 6,049' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I 4 -1/2" 5 OBa 4 -1/2" 5 OBb ' ' — 6075' H3 -1/2" HES X NIP, ID = 2.813" I 4 -1/2" 5 OBc 4 -1/2" 5 OBd � ' I 6,125' I — I3 - 1/2" HES X NIP, ID = 2.813" 1 ' , I 6,146' H3-1/2" HES XN NIP, ID = 2.750" I I3 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" F I 6,167' I . \I PBTD H 6304' L 6,169' H3-1/2" WLEG, ID = 2.992" I VAVAVAVAVAVAVAVAVAV 1 CSG, 26 #, L -80 BTC -M, .0383 bpf, ID = 6.276" I-I 6,387' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 10/29/08 ZJS PROPOSED COMPLETION WELL: L -222 PERMIT No: API No: 50-029 - SEC 34, T12N, R11 E, 2369' FSL & 1522' FWL BP Exploration (Alaska) bp 0 L -222 (P2b) Proposal $cblumberger Report Date: April 20, 2009 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 80.140° Structure F L-PAD / -222 Unit - WOA StYd TVD Vertical Section Origin: N 'ND Re R r e ceeDatum: Rotary 50 ft o0 Datum: a b i vo MSL Borehole: Ole0e Well: Plan L -222 : Plan L -222 � ��'' Sea Bed I Ground Level Elevation: 49.00 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 22.282° Survey Name I Date: L -222 (P2b) / April 20, 2009 Total Field Strength: 57702.695 nT Tort 1 AHD / DDI I ERD ratio: 55.363° / 3677.49 ft / 5.425 / 0.753 Magnetic Dip: 80.883° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 05, 2009 Location LaVLong: N 70.35079753, W 149.32276726 Magnetic Declination Model: BGGM 2008 Location Grid N/E YIX: N 5978343.900 ftUS, E 583412.300 ftUS North Reference: True North Grid Convergence Angle: +0.63780019° Total Corr Mag North 4 True North: +22.282° Grid Scale Factor: 0.99990790 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag I Gray Directional Comments Inclination Sub•Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deg1100ft ) Index (ftUS) (ftUS) RTE 0.00 0.00 80.15 -77.50 0.00 0.00 0.00 0.00 - -- 0.00 0.00 5978343.90 583412.30 N 70.35079753 W 149.32276726 G1 337.50 0.00 80.15 260.00 337.50 0.00 0.00 0.00 - -- 0.00 0.00 5978343.90 583412.30 N 70.35079753 W 149.32276726 KOP Bld 1.5/100 400.00 0.00 80.15 322.50 400.00 0.00 0.00 0.00 80.15M 0.00 0.00 5978343.90 583412.30 N 70.35079753 W 149.32276726 Bid 2.5/100 500.00 1.50 80.15 422.49 499.99 1.31 0.22 1.29 80.15M 1.50 0.29 5978344.14 583413.59 N 70.35079814 W 149.32275679 600.00 3.75 80.15 522.38 599.88 5.89 1.01 5.80 80.15M 2.25 1.34 5978344.97 583418.09 N 70.35080028 W 149.32272016 700.00 6.00 80.15 622.01 699.51 14.39 2.46 14.17 HS 2.25 1.94 5978346.52 583426.44 N 70.35080425 W 149.32265219 800.00 8.25 80.15 721.23 798.73 26.79 4.58 26.39 HS 2.25 2.35 5978348.78 583438.64 N 70.35081005 W 149.32255299 900.00 10.50 80.15 819.89 897.39 43.08 7.37 42.44 HS 2.25 2.66 5978351.74 583454.65 N 70.35081766 W 149.32242271 SV6 971.50 12.11 80.15 890.00 967.50 57.09 9.77 56.25 HS 2.25 2.84 5978354.30 583468.43 N 70.35082422 W 149.32231061 i 1000.00 12.75 80.15 917.83 995.33 63.23 10.82 62.29 HS 2.25 2.91 5978355.41 583474.46 N 70.35082708 W 149.32226155 1100.00 15.00 80.15 1014.91 1092.41 87.21 14.92 85.92 HS 2.25 3.12 5978359.78 583498.04 N 70.35083830 W 149.3 976 1200.00 17.25 80.15 1110.97 1188.47 114.98 19.68 113.28 HS 2.25 3.30 5978364.84 583525.34 N 70.35085128 W 149. 63 1300.00 19.50 80.15 1205.86 1283.36 146.50 25.07 144.34 HS 2.25 3.46 5978370.57 583556.34 N 70.35086602 W 149.3 551 1400.00 21.75 80.15 1299.45 1376.95 181.72 31.10 179.04 HS 2.25 3.60 5978376.99 583590.97 N 70.35088248 W 149.32131378 1500.00 24.00 80.15 1391.58 1469.08 220.59 37.75 217.34 HS 2.25 3.73 5978384.07 583629.18 N 70.35090065 W 149.32100289 SV5 1592.08 26.07 80.15 1475.00 1552.50 259.56 44.42 255.73 HS 2.25 3.84 5978391.16 583667.49 N 70.35091887 W 149.32069123 1600.00 26.25 80.15 1482.11 1559.61 263.05 45.02 259.17 HS 2.25 3.85 5978391.80 583670.93 N 70.35092050 W 149.32066330 1700.00 28.50 80.15 1570.90 1648.40 309.03 52.89 304.47 HS 2.25 3.96 5978400.17 583716.13 N 70.35094200 W 149.32029554 SV4 1738.96 29.38 80.15 1605.00 1682.50 327.88 56.12 323.04 HS 2.25 4.00 5978403.60 583734.66 N 70.35095081 W 149.32014476 1800.00 30.75 80.15 1657.83 1735.33 358.45 61.35 353.17 HS 2.25 4.06 5978409.17 583764.73 N 70.35096510 W 149.31990019 Base Perm 1825.88 31.33 80.15 1680.00 1757.50 371.80 63.63 366.31 HS 2.25 4.08 5978411.60 583777.85 N 70.35097134 W 149.31979345 1900.00 33.00 80.15 1742.74 1820.24 411.26 70.39 405.19 HS 2.25 4.15 5978418.78 583816.64 N 70.35098978 W 149.31947784 2000.00 35.25 80.15 1825.52 1903.02 467.35 79.99 460.46 HS 2.25 4.24 5978429.00 583871.80 N 70.35101600 W 149.31902915 2100.00 37.50 80.15 1906.03 1983.53 526.66 90.14 518.89 HS 2.25 4.32 5978439.80 583930.10 N 70.35104372 W 149.31855482 SV3 2181.65 39.34 80.15 1970.00 2047.50 577.40 98.82 568.88 HS 2.25 4.38 5978449.04 583979.99 N 70.35106743 W 149.31814899 WellDesign Ver SP 2.1 Bld( users) L- 222 \Plan L- 222 \Plan L- 222 \L -222 (P2b) Generated 4/20/2009 2:04 PM Page 1 of 2 • Measured Azimuth Vertical NS EW Mag 1 Grav Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Fasting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) I (deg) (ft) (ft ) (ft ) (ft ) (ft ) (deg) (deg /100ft ) Index (ftUS) (ftUS) 2200.00 39.75 80.15 1984.15 2061.65 589.08 100.82 580.38 HS 2.25 4.40 5978451.16 583991.47 N 70.35107289 W 149.31805556 2300.00 42.00 80.15 2059.76 2137.26 654.51 112.02 644.86 HS 2.25 4.47 5978463.08 584055.81 N 70.35110348 W 149.31753216 2400.00 44.25 80.15 2132.74 2210.24 722.87 123.72 712.20 HS 2.25 4.54 5978475.53 584123.01 N 70.35113542 W 149.31698542 SV2 2410.16 44.48 80.15 2140.00 2217.50 729.97 124.93 719.20 HS 2.25 4.55 5978476.82 584130.00 N 70.35113874 W 149.31692861 2500.00 46.50 80.15 2202.98 2280.48 794.03 135.90 782.32 HS 2.25 4.61 5978488.49 584192.98 N 70.35116868 W 149.31641618 2600.00 48.75 80.15 2270.37 2347.87 867.91 148.54 855.10 HS 2.25 4.67 5978501.94 584265.61 N 70.35120319 W 149.31582532 End Bld 2610.80 48.99 80.15 2277.48 2354.98 876.04 149.93 863.11 -- 2.25 4.68 5978503.42 584273.61 N 70.35120700 W 149.31576024 SV1 2911.83 48.99 80.15 2475.00 2552.50 1103.21 188.81 1086.93 - -- 0.00 4.79 5978544.78 584496.96 N 70.35131313 W 149.31394321 UG4 3391.90 48.99 80.15 2790.00 2867.50 1465.48 250.82 1443.86 - -- 0.00 4.93 5978610.75 584853.14 N 70.35148236 W 149.31104542 9 -5/8" Csg 3407.14 48.99 80.15 2800.00 2877.50 1476.99 252.79 1455.19 - -- 0.00 4.93 5978612.85 584864.45 N 70.35148773 W 149.31095343 UG4A 3437.63 48.99 80.15 2820.00 2897.50 1499.99 256.72 1477.85 - -- 0.00 4.94 5978617.03 584887.07 N 70.35149847 W 149.31076944 UG3 3993.90 48.99 80.15 3185.00 3262.50 1919.77 328.57 1891.44 - -- 0.00 5.06 5978693.47 585299.79 N 70.35169450 W 149.3.63 UG1 4816.88 48.99 80.15 3725.00 3802.50 2540.81 434.87 2503.32 - -- 0.00 5.20 5978806.56 585910.39 N 70.35198439 W 149.3 79 Drp 0.5/100 5113.29 48.99 80.15 3919.49 3996.99 2764.49 473.15 2723.70 LS 0.00 5.24 5978847.29 586130.31 N 70.35208877 W 149.30065452 Mbl 5121.69 48.95 80.15 3925.00 4002.50 2770.83 474.23 2729.94 LS 0.50 5.24 5978848.44 586136.54 N 70.35209173 W 149.30060385 5200.00 48.56 80.15 3976.63 4054.13 2829.71 484.31 2787.96 LS 0.50 5.25 5978859.17 586194.43 N 70.35211920 W 149.30013281 Mb2 5235.25 48.38 80.15 4000.00 4077.50 2856.10 488.83 2813.96 LS 0.50 5.26 5978863.97 586220.38 N 70.35213151 W 149.29992173 5300.00 48.06 80.15 4043.14 4120.64 2904.39 497.09 2861.53 LS 0.50 5.27 5978872.76 586267.85 N 70.35215404 W 149.29953546 Mc 5355.00 47.78 80.15 4080.00 4157.50 2945.21 504.08 2901.75 LS 0.50 5.28 5978880.19 586307.99 N 70.35217308 W 149.29920889 5400.00 47.56 80.15 4110.30 4187.80 2978.48 509.77 2934.53 LS 0.50 5.29 5978886.25 586340.70 N 70.35218859 W 149.29894277 Na 5451.29 47.30 80.15 4145.00 4222.50 3016.25 516.23 2971.75 LS 0.50 5.30 5978893.13 586377.84 N 70.35220621 W 149.29864058 5500.00 47.06 80.15 4178.10 4255.60 3051.98 522.34 3006.95 LS 0.50 5.30 5978899.63 586412.96 N 70.35222287 W 149.29835479 5600.00 46.56 80.15 4246.55 4324.05 3124.89 534.82 3078.78 LS 0.50 5.32 5978912.90 586484.65 N 70.35225687 W 149.29777156 L -222 Tgt OA 5691.89 46.10 80.15 4310.00 4387.50 3191.36 546.19 3144.27 LS 0.50 5.33 5978925.00 586550.00 N 70.35228786 W 149.29723983 OA 5691.91 46.10 80.15 4310.01 4387.51 3191.37 546.19 3144.28 LS 0.50 5.33 5978925.00 586550.01 N 70.35228787 W 149.29723975 5700.00 46.06 80.15 4315.62 4393.12 3197.20 547.19 3150.02 LS 0.50 5.33 5978926.06 586555.74 N 70.35229058 W 149.29719312 OBa 5799.53 45.56 80.15 4385.00 4462.50 3268.56 559.40 3220.34 LS 0.50 5.35 5978939.05 586625.91 N 70.35232386 W 149.29662220 5800.00 45.56 80.15 4385.33 4462.83 3268.90 559.45 3220.67 LS 0.50 5.35 5978939.12 586626.24 N 70.35232401 W 149.29661953 OBb 5877.82 45.17 80.15 4440.00 4517.50 3324.27 568.93 3275.23 LS 0.50 5.36 5978949.19 586680.68 N 70.35234983 W 149.29617656 5900.00 45.06 80.15 4455.65 4533.15 3339.99 571.62 3290.71 LS 0.50 5.36 5978952.05 586696.14 N 70.35235715 W 149. 082 OBc 5962.61 44.75 80.15 4500.00 4577.50 3384.18 579.18 3334.26 LS 0.50 5.37 5978960.10 586739.59 N 70.35237776 W 149.2727 6000.00 44.56 80.15 4526.60 4604.10 3410.46 583.67 3360.15 LS 0.50 5.38 5978964.88 586765.43 N 70.35239001 W 149.29548705 OBd 6039.79 44.36 80.15 4555.00 4632.50 3438.33 588.44 3387.61 LS 0.50 5.38 5978969.95 586792.83 N 70.35240300 W 149.29526410 6100.00 44.06 80.15 4598.16 4675.66 3480.32 595.62 3428.97 LS 0.50 5.39 5978977.60 586834.11 N 70.35242257 W 149.29492824 6137.29 43.87 80.15 4625.00 4702.50 3506.21 600.05 3454.48 LS 0.50 5.39 5978982.31 586859.56 N 70.35243463 W 149.29472112 OBe 6137.31 43.87 80.15 4625.01 4702.51 3506.22 600.05 3454.49 LS 0.50 5.39 5978982.31 586859.57 N 70.35243464 W 149.29472105 6200.00 43.56 80.15 4670.32 4747.82 3549.54 607.46 3497.18 LS 0.50 5.40 5978990.20 586902.17 N 70.35245483 W 149.29437445 6300.00 43.06 80.15 4743.09 4820.59 3618.14 619.20 3564.76 LS 0.50 5.41 5979002.68 586969.61 N 70.35248680 W 149.29382572 TD / 7" Lnr 6387.29 42.62 80.15 4807.10 4884.60 3677.49 629.35 3623.24 - -- 0.50 5.43 5979013.48 587027.97 N 70.35251447 W 149.29335087 Legal Description: Northing (Y) fftUS1 Easting (X) fftUS1 Surface : 2619 FSL 3501 FEL S34 T12N R11E UM 5978343.90 583412.30 L -222 Tgt OA : 3165 FSL 356 FEL S34 T12N R11E UM 5978925.00 586550.00 BHL : 3248 FSL 5157 FEL S35 T12N R11E UM 5979013.48 587027.97 WellDesign Ver SP 2.1 Bld( users) L- 222 \Plan L- 222 \Plan L- 222 \L -222 (P2b) Generated 4/20/2009 2:04 PM Page 2 of 2 by Schlumberger WELL L -222 (P2b) I FIELD Prudhoe Bay Unit - WOA I STRUCTURE L -PAD Magnetic Parameter Surface Location 98027 Alaska State Planes, Zone 04. US Feet Miscellaneous Model: BGGM 2008 Dip 80.883° Data: September OS 2009 Let: 970212.071 NoMi09 597834390 PUS Grid Gone: .063780019' Sat. L -222 TVG Ref: Rotary Table (77.500ab000 MSL) Meg Dec: 422.282' FS: 57702.7 nT Lon: W14919 21262 Ealing: 583412.30 M/S Scale Fad: 02999079037 Plan: L -222 (P2b) Soy Date: Apt120. 2009 0 800 1600 2400 3200 4000 RTE 0 0 KOP Bld 1.5/100 Bld 2.5/100 • 800 d 800 1600 "'_.._.._.._.._.._. _.._.._ � _.._.._.._.._ ._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._..-.._.._.._.._.._.._.._.._.._. ._.._.._.._.._.._.._.._.�.._... 1600 End Bld CO 2400 2400 9 -5/8" Csg CO U CO r. 3200 3200 • Dip 0.51100 • 4000 „ 4000 _.._.._.._.._.._.._. _.._.._.._.._.._.._.. • - _.. _.. _. _.._.._.._.. _.._.._.._ _.._.. _.._..- ..- .._.._ _ _ • 'b._ ._.. _.._.. _.._ ._... • _.._.._.._.._.._.._ _.._.._.._.._.._.._.._.._ _.._.._.._.._.._.._.._.._.._.._.._.._.._.._..-.._ .._..- .._.._.._.._.._.._.._..i. _.._.. • a .1157767 • 4800 L -22 (P2b) 4800 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 80.14 °, Scale = 1(in):800(ft) Origin = 0 N / -S, 0 E / -V • by 0 Schlumberger • WELL L -222 (P2b) I FIELD Prudhoe Bay Unit - WOA I STRUCTURE L -PAD Magnetic Parameters Surface Location NAM] Alaska Stale Planes. Zone 04, US Feet Meoue Model: BGGM 2008 Dip 80B83° Date. September 05. 2009 Let 870212871 Northing: 59]834390 ftUS Grid Cone 4083780019° Std: israllan L -222 TVD Ref: Rotary Table (77.50 ft above MSL( Mag Dec: 422282° FS: 57702.7 nT Lon. W149 19 21.982 Easbng: 583412.30 MIS Scale Fact 0.9999079037 Plan: L-222 (P2b) Sr, Date April 20, 2009 0 500 1000 1500 2000 2500 3000 3500 1500 d G 1500 • 1000 1000 °N A Z TD 12° Lnr 4 •• L- 222Tgt OA 8 -222 (P2b Drp 0.51100 ,, ) O 1D 500 500 c to 9.518- c • u Si End Bld CO U -11 U) CO • V 0 < 0 • V RTE Bld 2.51100 KOP Bld 1.5/100 -500 -500 0 500 1000 1500 2000 2500 3000 3500 c« W Scale = 1(in):500(ft) E »> BP Exploration Alaska Antiollieion Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well Plan L-222 Project: Prudhoe Bay TVD Reference: L-222 Plan @ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L-222 Plan I@ 77.50ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well Plan L-222 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan L-222 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #2 L-222 Offset ND Reference: Offset Datum Reference Plan #2 L-222 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200+ 100/1000 of refer Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results-Limited-by: —Maximum center-centerdistance of 835.88ft Error Surface Elliptica Survey Tool Program Date 4/20/2009 From To (ft) (ft) Survey (Wellborn) Tool Name Description 28.50 500.00 Plan #2 L-222 (Plan L-222) GYD-GC-SS Gyrodata gyro single shots 500.00 1,900.00 Plan #2 L-222 (Plan L-222) MWD MWD - Standard 500.00 3,270.00 Plan #2 L-222 (Plan L-222) MWD+IFR+MS MWD + IFR + Multi Station 3,270.00 6,387.29 Ptarr#2 L-222 (Plan L-222) MWDAFR+MS MWD + IFR + Multi Station 4/21/2009 Page 2 of 5 COMPASS 2003.16 Build 70 ilL - BP - Exploration Alaska • n icoision Report Company: North America - ALASKA - BP Local Co- orcilnate Reference: Well Plan L -222 Project: Prudhoe Bay TVD Reference: L -222 Plan @ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L -222 Plan @ 77.50ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Welk Plan L - 222 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Weilbore Plan L - 222 Database: EDM .16 - Anc Prod - WH24P Reference Design Plan #2 L -222 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured , Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore - Design (ft) (ft) (ft) (ft) PB L Pad L-03 -L-03-103 . __ - - -- _.. - -_- 700.00 - 721100 - 240:49 - 12.61 1Fdjur Risk L -102 - L -102 - L -102 691.15 695.00 184.62 10.50 174.12 Pass - Major Risk L -102 - L- 102PB1 - L- 102PB1 770.72 775.00 184.24 12.48 171.77 Pass - Major Risk L -102 - L- 102PB2 - L- 102PB2 770/2 775.00 184.24 12.48 171.77 Pass - Major Risk L -103 - L -103 - L -103 486.40 490.00 119.68 7.94 111.73 Pass - Major Risk L -104 - L -104 - L -104 408.25 410.00 195.20 6.87 188.33 Pass - Major Risk L -105 - L -105 - L -105 553.81 560.00 217.82 9.98 207.84 Pass - Major Risk L -106 - L -106 - L -106 790.89 810.00 192.84 12.87 180.04 Pass - Major Risk L -107 - L -107- L -107 547.26 555.00 260.47 10.64 249.84 Pass - Major Risk L -108 - L -108 - L- 108 642.61 655.00 220.33 11.41 208.93 Pass - Major Risk L- 119 -L- 1-19 L- 1- 't9_ -_- 521.04 - 525:00 73 6R 8.82 64.86 - -- Passer- Risk - - --- L -120 - L -120 - L -120 724.20 730.00 33.51 12.16 21.50 Pass - Major Risk L -200 - L -200 - L -200 500.00 505.00 212.08 8.95 203.23 Pass - Major Risk - U200 - L -2OOL1 = L= 2OOCr 500:0 505.0 212A87 __ _ 8.95 20323 Pass - Major Risk L -200 - L -200L2 - L -200L2 500.00 505.00 212.08 8.95 203.23 Pass - Major Risk I -201 - L -201 - 1 201__ - - _ - -_ 558_71_ ___ 565.00 84.511 9.77 - _74.76- - Pass MajoLRisk_. - - -- L -201 - L -201 L1 - L -201 L1 558.71 565.00 84.50 9.77 74.76 Pass - Major Risk L -201 - L- 201L1PB1 - L- 201L1PB1 558.71 565.00 84.50 9.72 74.80 Pass - Major Risk L -201 - L -20112 - L -201L2 558.71 565.00 84.50 9.72 74.80 Pass - Major Risk L -201 - L -201L3 - L -201L3 558.71 565.00 84.50 9.77 74.76 Pass - Major Risk L -201 - L- 2O1L3PB1 - L- 201L3PB1 558.71 565.00 84.50 9.72 74.80 Pass - Major Risk _ L -201 - L- 201PB1 - L- 201PB1 558.71 565.00 84.50 9.72 74.80 Pass - Major Risk L -201 - L- 201PB2 - L- 201PB2 558.71 565.00 84.50 9.72 74.80 Pass - Major Risk L- 20-2 - 242 - L-20-2 471.56 - 475.00 - 194-.87- T96 1-86 91-Pass-- Major-Risk- L-202 - L -202L1 - L -202L1 471.56 475.00 194.87 7.96 186.91 Pass - Major Risk L -202 - L -202L2 - L -202L2 471.56 475.00 194.87 7.96 186.91 Pass - Major Risk L -202 - L -202L3 - L -202L3 471.56 475.00 194.87 7.96 186.91 Pass - Major Risk L -204 - L -204 - L -204 353.86 355.00 197.55 6.17 191.37 Pass - Major Risk L -204 - L -204L1 - L -204L1 353.86 355.00 197.55 6.17 191.37 Pass - Major Risk L -204 - L -204L2 - L -204L2 353.86 355.00 197.55 6.17 191.37 Pass - Major Risk L -204 - L -204L3 - L -204L3 353.86 355.00 197.55 6.17 191.37 Pass - Major Risk L-2D4 - L -204[4 - L - - - 3518 - - X55700 19T.55 - -- 6.17 191:37 Pass - Major Risk L -204 - L -204L4 - Plan #2 353.86 355.00 197.55 6.22 191.33 Pass - Major Risk L -710 - L-210- I -910 - 860 34 . -_ 870 00 2213- 14 07 811 __Pa s - Major Rsk L -210 - L- 210PB1 - L- 210PB1 860.34 870.00 22.13 14.07 8.11 Pass - Major Risk L -212 - L -212 - L -212 769.79 795.00 166.79 12.41 154.67 Pass - Major Risk L- 212 - L- 212PB1 L-212PB1 800.00 - 824:00 162.64 12.75 150:23 Paste = Maj *LRisk L -212 - L- 212PB2 - L- 212PB2 769.79 795.00 166.79 12.41 154.67 Pass - Major Risk L -213 - L-213 - L-213 339.39 340.00 234.85 5.71 229.14 Pass - Major Risk__..-._...,, L -214 - L -214 - L -214 784.37 795.00 153.31 13.25 140.06 Pass - Major Risk L -214 - L -214A - L -214A 784.37 795.00 153.31 13.25 140.06 Pass - Major Risk L -215 - L -215 - L -215 505.87 510.00 108.13 9.20 98.94 Pass - Major Risk L -215 - L- 215PB1 - L- 215PB1 505.87 510.00 108.13 9.20 98.94 Pass - Major Risk L -215 - L- 215PB2 - L -215 PB2 505.87 510.00 108.13 9.20 98.94 Pass - Major Risk L -216 - L -216 - L -216 603.25 615.00 127.00 11.88 115.12 Pass - Major Risk L -217 - L -217 - L -217 518.99 525.00 159.84 9.41 150.43 Pass - Major Risk L-2-19 L 219- -L 219 622.54 625.00 18.76 1-3:3 5,42 Pass Major-Risk- L -221 - L -221 - L -221 567.00 575.00 243.11 10.53 232.58 Pass - Major Risk L -250 - L -250 - L -250 485.18 490.00 225.87 9.66 216.21 Pass - Major Risk L-25(12 - L 250 - 485.1 8 490.00 - 2/ 7 578/ 906 21 - Major Risk L -250 - L -250L2 - L -250L2 485.18 490.00 225.87 9.71 216.16 Pass - Major Risk J -950 - t as0PR1 _ L250P1 1 -_ - - -- 485_ _490.00_ 22 8T_ _ -- -- - - - -_- 66 216 91 Pass -- MajorRisk Plan L -203 (N -Q) - Plan L -203 OBd NW - Plan #11 580.40 590.00 148.73 10.85 137.89 Pass - Major Risk 4/2172009 1 :03 :33PM Page 3 of 5 COMPASS 2003.16 Build 70 BP Alaska n icollision Report -_- III Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan L -222 Project: Prudhoe Bay TVD Reference: L -222 Plan @ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L -222 Plan © 77.50ft (Nabors 9E8) Site Error: 0.00ft North Reference: True Reference Well: Plan L -222 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan L -222 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #2 L -222 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warn Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) PB L Pad P1an 203 - (N O) - Ptari L- 203LY0Bd - Plan# 580.40 590.00 14&73 - Pass - MajorRisk Plan L -203 (N -Q) - Plan L -203L2 OBc SE - Plan # 580.40 590.00 148.73 10.85 137.89 Pass - Major Risk Plan L-203 (N -Q) - Plan L- 203L2 -01 OBc NW - PIE 580.40 590.00 148.73 10.85 137.89 Pass _ Maj Risk__ Plan L -203 (N -Q) - Plan L -203L3 OBa - Plan #6 L- 580.40 590.00 148.73 10.85 137.89 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203L4 Nb - Plan #7 L -2( 580.40 590.00 148.73 10.85 137.89 Pass - Major Risk Plant- 203 (N -Q) - Plan - L-20 -- Plan- #2 -L-24- 3 "^ 590:00 14&73 10.85 13789- Pass-Major Risk Plan L -223 - Plan L -223 - Plan #3 L -223 659.67 685.00 259.85 12.22 247.69 Pass - Major Risk 4/2172809 f 03 :33PM - Page 4 of 5 COMPASS 2003.16 Build 70 r Project: Prudhoe Bay • Site: PB L Pad Well: Plan L -222 Wellbore: Plan L -222 Design: Plan #2 L -222 From kop to TD Scan interval 100 ft Scale 1:100 All wells Major Risk o L- 1- - 215P8_2 _L.12 ta%L-120 r , / ®,� , 1 1 L -219/L -219 330 2011_- 201PBa' ?1 � ll I _ 30 14 i ,� aqA DA. 19 ...\-:" 216 °3 32 , M ----.--- ,. r 3 / 3i ' 18 0 / -- 13 7 30 r-` r,, 0 l .. -200 - 12 i �23 N � 1 L - 11.42119 27 / 27 / ��. W t / 300 �. 60 / Plan L- 221Plan 4 • lk / L- 23 % , / ' I 1 ...-. 4 , 1 Plan L - %03 tN :Plan' • ' _205L5 0BE`Er U 13 • L 2�501L- `250PB1 I ( �� i5 / } , v7l, 121 �. r 3 23 / / '\ . 12 • 417 (� r}w, -118( • '9 '' / I4 11 i c. ' , 9 13 _ f 14 1 � ' 1 $ 7 t 3 1 l 21 L -2101L -210 19 10 1 ilk s . : l ' 3 1 u r /13 P1 . 20 i' 7 270 o �� • _ 1 _, —+7--� _ T — 90 f i� � i i i $ 10 rr ft- - ,S , 14 1 , ' ' -.0 � `,0 vo. 212lL-2 1 1 1:t 3'1- o T 10 1 12 13 %7 ,,,, � a�e / 10 9 L 7115 -1 13 1 c o 12': �+' 11 12 /15 � 1¢ 15° / 10 13 16 17 Wi g - 8 � % L- 214IL -214A 240 10 1 � \ 8 j g 8 �� $ h 89 ' / / 120 S 3 q. . _ " — � . 1�1 L- 03lL -03 11 0 K ^ 1 ,� -- .I., 1 � 0 / \ 12 1 S '1. S ` '�c g 3 / .0 18 / \ ,_ t {► 0 37 15 / 1 /19 24 � s 1 8 r 1� '2324. -3 1 L , - - � it2211 2.0 17 .r L 21 • � • 10 18 / LLQ1 t ` . i ce ��4 2 30c �i� 20 1 ' ,, t 2, / 21U �} -. L -102/1 -102 ......._, .4 j am \ ' 15 � : si `P 111Le L - 4. #21 18u Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [100 ft/in] EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 6000000 i / 11_, A AEO1 5950000 L-222(surface) H 5900000 • 40 CFR 147.102 (b)(3) I 5850000 400000 500000 600000 700000 800000 f Orion Pool /Injection Area / t 111 1 Well Base Map Al Prudhoe Bay kilim 1 1 =ou teary .4w ..... mail , 2 _.. 4, ill ' Red Outline - Orion � ... _,. -� Poolllnjection Area !mot f.at i.,17— 1i .:.-.11. ir "'sm.:- b ,, - ",■ - . Orion Development Potygon 1 ,4 � � Oran Production Well It/2031 •, 1► 1 Completed Pre 811108 �- , .. ?yi ..� r . k ;r# Pad P : Orton Production Well ' 21 1 - rit Completed between ' :1 811108 and 811109 L ` - ZZ2v :, Orton Production Weft 1 ,,, • Planned for Completion 0 0 °. 471171 �' betv�een811109and 1 1111 1111111.1111191 2/31/10 Orion Injection Well A 203 L Completed Pre-8/1/08 , Z Pad . .,, .. la +, Orton Injection Well .. Completed between 4 a 1 1 �, » za 21 811.108 and 811109 ..,. ` 'l''"` "" #.97Y -`I Y ftrM r il l . l/M.sl l...l .1;Mi a. Orion injection Web Planned for 811109 to 1213112010 } L 20 Orion ParlicipatngArea r..... Boundary rii... I Prudhoe Bay find Boundary Alaska Department of Naturilsources Land Administration System. Page 1 ofetr Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28238 Printable Case File Summary See Township, Range, Section and Acreage? �!) Yes i ; No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28238 Mtal: Search for Status Plat Updates As of 10/07/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/28/2007 Case Subtype: NS NORTH SLOPE Last Transaction: PAXN1 PARTICIPATING AREA EXPANDED Meridian: U Township: 012N Range: 011E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 26 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 35 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 36 Section Acres: 640 Legal Description 05 - 28 - 1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -16 012N- 011E -UM 25,26,35,36 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT TRACT 19 OIL RIM AND GAS CAP PARTICIPATING AREAS T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA • • http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2823... 10/7/2009 Alaska Department of Naturasources Land Administration System. Page 1 of \Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28239 Printable Case File Summary See Township, Range, Section and Acreage? O Yes 0 No New Search LAS Menu l Case Abstract I Case Detail I Land Abstract APIA, File: ADL 28239x__. Search for Status Plat Updates As of 10/07/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 011E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 28 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 33 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14 -17 012N-011E-UM 2 7, 28, 33, 34 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA'S PRUDHOE BAY UNIT • http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2823... 10/7/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME / 7 3'' /-,0024.2 PTD# .209/19 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: ,C,eC/4,4OE' 3.0y POOL: aiexvii SII" Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 p :''4Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L- 222 Program SER Well bore seg ❑ PTD#: 2091190 Company BP EXPLORATION (ALASKA) INC Initial Class /Type SER / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2569 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 10/7/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 26. • 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.0306.1.A),(j,2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA Well inside AEO 1 (CFR 40) 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC to be 1000' below surface shoe 22 CMT will cover all known productive horizons Yes !23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If a re -drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. All wellbores pass major risk criteria, 27 If diverter required, does it meet regulations Yes Paddle removal acceptable <1000' Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum fm pressure =2180 psi (8.7ppg) will drill with 9.4 ppg LSND mud GLS 10/7/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 1699 psi Will test BOP to 4000 psi ill 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S reported on L -pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR performed. All wells within 1 /4mi OK, 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S for well L -120 is 200ppm (9/12/08). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 10/7/2009 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] _ No 1 Geologic Engineering Pub 1 Date: Date Date Commissioner: C fission . mis r ilj - 07 4011.1 Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L -222 Program SER Well bore seg ❑ s 4 - -- — -- - _ _ - - PTD#: 2091190 Company BP EXPLORATION (ALASKA) INC _ Initial Class/Type SER / PEND GeoArea 890 Unit 11650 _ On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval N Yes 13 Can permit be approved before 15 -day wait ACS 10/7/2009 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 26. • 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) NA \` 17 Nonconven. gas conforms to AS31.05.0306.1.A),(j.2.A -D) NA ' , 18 Conductor string provided InCmpt Engineering 19 Surface casing protects all known USDWs InCmpt 20 CMT vol adequate to circulate on conductor & surf csg InCmpt 21 CMT vol adequate to tie -in long string to surf csg InCmpt 22 CMT will cover all known productive horizons InCmpt 1 23 Casing designs adequate for C, T, B & permafrost InCmpt 24 Adequate tankage or reserve pit InCmpt \ 25 If a re- drill, has a 10 -403 for abandonment been approved InCmpt 26 Adequate wellbore separation proposed InCmpt 27 If diverter required, does it meet regulations InCmpt Appr Date 28 Drilling fluid program schematic & equip list adequate InCmpt 29 BOPEs, do they meet regulation InCmpt 30 BOPE press rating appropriate; test to (put psig in comments) InCmpt 3 • 1 Choke manifold complies w /API RP -53 (May $4) InCmpt \ 32 Work will occur without operation shutdown InCmpt 33 Is presence of H2S gas probable InCmpt 34 Mechanical_condition of wells within AOR verified (For service well only) InCmpt 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S for well L -120 is 200ppm (9/12/08). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 10/7/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering Public Commissioner: Date: Commissioner: Dat Commissioner Date
