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Home My WebLink About2011 Kenai Gas FieldMarathon Alaska Production LLC P.O. Box 1949 35350 Kalifornsky Beach Road Kenai, AK 99611 Telephone (907) 283-1371 Fax (907) 283-1350 February 10, 2012 tri 14.0 Marathon Oil Commissioners: John Norman, Dan Seamount, Cathy Foerster Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 AnchorsAK 99501 3539 RECEIVED FEB 13 2012 ge' Alaska Oil & Gas Cons. Commission Anchorage Reference: Kenai Gas Field Storage Injection Order 7 2011 Annual Gas Storage Performance Evaluation Dear Commissioners: Marathon Alaska Production LLC (Marathon) respectfully submits the attached information to fulfill the requirements of Rule 5 of Storage Injection Order #7, dated April 19, 2006. Rule 5 requires, in part: "An annual report evaluating the performance of the storage injection operation must be provided to the Commission no later than March 15. The report shall include material balance calculations of the gas production and injection volumes and a summary of well performance data to provide assurance of continued reservoir confinement of the gas storage volumes." After almost 48 years of continuous production, the Sterling Pool 6 continues to exhibit tank - like behavior. Marathon has not observed, and has no information indicating, any change to this behavior as a result of gas injection and storage operations which began on May 8, 2006. Marathon has conducted gas storage operations in compliance with the rules and conditions of SIO #7. All required data, other than form 10-413 as explained below, have been submitted to the AOGCC. For the annual period ending December 31, 2011, the total volume of gas injected into Pool 6 was 2,001,884 mscf. The total volume of stored gas withdrawn was 2,255,848 mscf. The total volume of native gas withdrawn was 2,255,848 mscf. The maximum calculated reservoir bottom -hole pressure during the 2011 injection cycle was 289 psia (KU 31-7X, July 2010) below the maximum of 300 PSI permitted under Rule 4 of SIO -7. Attached, please find Exhibit #1, a summary of the results of a recent update to the Sterling Pool 6 reservoir model, which is submitted to satisfy the annual performance evaluation requirements for material balance calculations. The reservoir pressures used in the model were shut-in tubing pressures obtained from our SCADA system which were converted to bottom -hole pressures at mid -perforation. Additionally, the field was shut in on August 18, 2011 to obtain the pressures. Modeling work shows an expected direct response to injection and withdrawals from the reservoir prior to 2011. Each observed shut-in well pressure prior to 2011 correlated well with the model prediction. The observed static pressures gathered are considerably different from the expected P/Z line (Exhibit 4). The reason for this variation can be explained by examining the pressure distributions predicted by the simulation model (Exhibit 10) and the reasons listed on page three. There is an aerial as well as temporal variation of pressure in the reservoir. This implies depending upon the location of the specific wells chosen for pressure measurements and the time of the year when the pressures are measured, the average measured pressure could be higher or lower than P/Z line. This is consistent with the observed departures from the P/Z values in Exhibit 4. Exhibit #2 is a plot showing the performance of the injection wells (KU 31-07X, 23X-06 and 21-06RD) during 2011. Exhibit #3 is a table showing monthly injection and withdrawal volumes plus allocated balances between Native and Stored gas. Exhibit #4 is the original P/Z plot contained in the application for gas storage. Exhibit #5 is a plot showing monthly averaged production rates, injection rates and field average pressure. Although Form 10-413 appears to be required by statute, the form has not been submitted because we interpret it to be applicable only to enhanced recovery projects rather than gas storage projects. Additional guidance is requested regarding the applicability and necessity of Form 10-413 for this gas storage project. If you have any questions, please do not hesitate to contact me at (713) 296-3477or Steve. huddlestona-marathonoil. com Sincerely, X116111 -1 - Steve Huddleston SUBSURFACE MANAGER MARATHON OIL COMPANY Enclosures (Via Certified Mail) cc: Wayne Svejnoha, BLM William Barron, Alaska DNR, Dept of Oil & Gas Jim Senn, Marathon Files 2 Exhibit #1 (1A — 1 M) Comparisons of Observed Pressures vs. Expected Pressures from Eclipse Model • KDU-5 • Well 43-06RD • Well 34-32 • Well 34-31 • Well 33-07 • Well 33-06 • Well 31-07x • Well 23x-06 • Well 21-06RD • Well 14x-06 • Well 14-32 • Well 13-06 • Well 22-6X For each of the wells listed above, two plots are presented showing historical observed shut- in pressures against those predicted by the Eclipse simulation model. The upper plot encompasses the entire historical life of the Pool 6 reservoir. The lower plot shows the same data beginning in the Year 2007. As can be seen for each of the wells, there is, in general good agreement between the pressures predicted by the simulation model and those observed at the individual wells prior to 2011. There do appear to be some minor differences for the historical pressures during 2007-2011 when plotted on an expanded scale. The minor variation could be attributed to the following reasons: 1) Simulation uses average monthly production rates rather than daily rates. 2) Some of the observed pressures are obtained from SCADA, which are less accurate as compared to test gauges used for biannual pressure measurements. Conclusions • Eclipse Model was updated to include production and injection volumes through December 2011 • The pressures predicted by the Eclipse model were compared to pressures observed in the various wells in 2011 • The pressures observed in the various wells compared favorably with those predicted by the simulation model prior to 2011 • Storage Unit did not exceed maximum allowable pressure of 300 psia • There is no evidence of containment issue Sterling Pool 6 SIO7 Exhibits February 2012 MarathonOil Well Bottoin Hole Pressure (5) frxv s..�a.a Mer e.a a �.v_rar f_.. 3000 2000 i n w 1000 - - - n' lal- 0 111965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 1/2000 1/2005 1/2010 Dote —Simulated SBHP- Eclipse —Well Gas Production Rate a Observed SBHP till 2007 400 14 300 i - -- -- - _ --' - 0 10 00 c: v� 200 0 0 � d U C o N 6 v O a' EL 100 4 0 0 p 1/2007 1/2008 112009 1/2010 1/2011 1/2012 Dote - — ardr aFu�ae MCu rode )aa_Mr>_avi 3000 2000 1000 a` I 0 1/1965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 112000 1/2005 1/2010 Date -Simulated SBHP- Eclipse -Well Gas Production Rete ° ° Observed SBHP till 2007 400 g I 14 300 12 o 3 i Q O O I \ i V) O 200 o ( 1 _ i I� o a 100 .. _ _. 4 6 I C? i 0 1/2007 1/2008 1/2009 1/2010 1/2011 1/2012 Date srHr +.,.u.e�MM'ied a �.nNr}_ten 3000 2000 n 1000 _ a 0 l I 1/1965 111970 1/1975 1/1960 1/1985 1/1990 1/1995 1/2000 1/2005 t/207n Date Simulated SBHP - Eclipse -Well Gas Production Rate 0 o Observed SBHP till 2007 400 16 14 300 I i - 12 M O x i 7 a > o p G � L\i U J [n 200 8 m 0 00- 0 "a 00 10 c 0 m v _0 a 0_ 100 - - {. 4 O I U 2 0 0 T 1/2007 1/2008 112009 1/2010 1/2011 1/2012 Date 'Well Bottorn HolePrmsiire (34-31) a (wn�l — eeMe 4mu�e Mew _ calor x mn� 3000 2000 1000 n i _ - 1/1965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 1/2000 1/2005 1/2010 Dole -Simulated SBHP - Eclipse -Well Gas Production Rete c c Observed SBHP till 2007 400 Ig 14 300 - 12 < O X _.... 10 Q p V 200 0 8 a) M Ij o Of n c O t ' � a` d. 100 4 9 V 2 0 0 1/2007 1/2008 1/2009 1/2010 1/2011 1/2012 Dole Well Bottom Hole Pressure (33-07) -- 9lM�swa�aMM•r�e Ynfa�_l_esrf 3000 2000 V�. 1000 - a' 111965 1 /1970 1/1975 1/1980 1/1985 1/1990 1/1995 1 /2000 1/2005 112010 Dote —Simulated SBHP - Eclipse -- Well Gas Production Rete — Observed SBHP till 2007 400 IF, i4 300 - - - - 12 O 10 a L� V 200 N C a o 3 6 v O n — a- 100 100 4 0 c� 0 1/2007 1/2008 1/2009 112010 1/2011 1/2012 Date Well Bottoin Hale Pressum (33-06) -eexr s..wa(xNM9_lan iur)_o.y 3000 2000 i 1000 I 0 1/1965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 1/2000 1/2005 1/2010 Date -Simulated SBHP - Eclipse -Well Gas Product on Rete 4 a Observed SBHP till 2007 400 16 14 300 12 rn O X 10 O 00 V) N 200 _ 8 a> o... O O o* p o � / v 6 v O � v � O o_ � 100 n a � 2 0 0 1/2007 1/2006 1/2009 V2010 1/2011 112012 Date N 3000 —j 2000 1000 a' 0 1/1965 111970 1/1975 1/1980 1/1985 9/1990 1/1995 1/2000 1/2005 1/2010 Date 1 -Simulated SBHP - Eclipse —Well Gas Production Rete I Observed SBHP 511 2007 400 16 14 300 12 O X } l 10 p V 200 8 O O n i � �C? O 6 V v � O a � 100 q C^ LF 2 0 0 112007 1/2008 1/2009 1/2010 1/2011 1/2012 Date 111970 111975 1/1950 Dole 1 -Simulated SBHP - Eclipse -Well Gas Production Rate Observed SBHP hll 2007 400 16 14 300 12 r�'1 I O x r 10 O 000 L U p (n 200 - - 8 0. 0 v � c _ � 6 v 4' O a � 100 4 O C� 2 0 0 112007 112008 1/2009 112010 112011 11201.2 Date 3n00 2000 N a a 3 y 1000 a` i 0 1/1965 1/1970 1/1975 1/1980 1/1985 111990 1/1995 1/2000 112005 1/2010 Dote - Simulated SBHP - Eclipse - Well Gas Production Rate Observed SBHP till 2007 400 p 14 300 12 r�-> O X 10 Q U N 200 8 w O a 0 C O 0 � 6 C a a I1 100 4 0 71 FIn 112007 1/2008 112009 1/2010 112011 +/?012 Date 0 1/1965 1/1970 111975 1/1980 1/1985 111990 111995 Dote Simulated SBHP - Eclipse -Well Gas Production Rate Observed SBHP till 2007 400 16 14 300 12 O X r 10 ap ✓ O � V 7 V) 200 8 0 Id c n O� O O O C) Li O a tl n 100 q o C� 2 p 0 1/2007 112008 1/2009 1/2010 1/2011 1/2012 Date ■ 1000 7 a 0 1/1965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 1/2000 1/2005 1/2010 Date -Simulated SBHP - Eclipse Well Gas Production Rate Observed SBHP till 2007 400 16 14 300 12 M o_ X d to 0 0 V V) 200UZ r g n u OOC, O O O too 4 C, 2 00 F7F IF 1/2007 1/2008 1/2009 1/2010 112011 1/2012 Date Well Bottom Hole Prcssurc 3-06) —_ leer e`ml�a M[w rm.0 �anlarJ_mr) 3000 _.e 2000 I i 1000 0 1/1965 1/1970 1/1975 1/1980 1/1985 1/1990 1/1995 1/2000 112005 1/2010 Date M, -Simulated SBHP - Eclipse ---- Well Gas Production Rate a Observed SBHP till 2007 400 to 14 300 12 < O k } 10 C) 1. O O O U N 200 - - 8 m 0 Of d O a' tl N 100 4 O 2 0 0 1/2007 1/2008 1/2009 1/2010 1/2011 1/2012 Date 3000 2000 0 111970 1/1975 1/1980 1/1085 111990 1/1995 1 /2000 1/2005 112010 Date -Simulated SBHP- Eclipse -Well Gas Production Rete ° ° Observed SBHP till 2007 400 16 .. 14 3u0 12 O X 10 Q O LL U N tun 8 Q, O Dp .� 00 C O 6 V N � N � o` Il 100 4 0 C9 2 0 0 1/2007 1/2008 1/2009 1121010 1/2011 112012 Date Pool 6 Shut -In Surface Pressures August 2011 Wells had been Sit auorox. 48 hrs. Well Test Gauge Psig Test Gauge Psis Mid-Perf TVDSS Mid -Pert TVD Mid -Pert MD Perforated Sand Calc'dM1dPerf (TVD) BHP psis COMMENTS KDU 5L --------------- ---------- 158 ----_-----_--- 172 4 490 4.578 5 162 C-1 189 Calibrated gauge placed on well. KU 13-6L -- - - - - 159 - --- •------ ----------------------- 173 ---------------------- --------------- 4 476 ------- -- - -----------------------------------------------__ 4,570 - -- 5,223 -- -- - -- - C-1 - -_ - - - - - - -- - - - 190 -- ---•-------- - .._....._.__....... - -- - - __-------------- Calibrated gauge placed on well -----------•- -- ... -- - - --------------------- KU 14-32 A 158 173 4,520 4,6075.316 5;316 C-1 189 Calibrated gauge placed on well. KU 14X-06 AN -------------------------- 162 -------------------- 176 ------- - ----------- --- 4,403 -- ------- ----------------------- 4,498 ----------- 4,498 ------ ---------- ------ - -- — - - C-1 C-2 --------------------- - ---- ........ 194 - — ------------- - - - -- -- -- - - - - - - - - Calibrated gauge placed on well. - -- - ------------------ - - ------------- KU 21 -SRO _ _-_-- - 159 - - - - - -- 174 -- -- - 4.482 - - --_ 4.562 _ _ __ 5,280 - - - - C-1 -- - - --- - - 190 -- — --- - Calibrated gauge placed on well - - ----------------------- ------------------ ----.. KU 22-6X ---------------------- 157 -----------------•-• 172 -••-•--•--•--•----- ....... -_--•-- 4.537 ------------- ------------ -------------------•----- 188 __-- _ _- _ - Calibrated gauge placed on well _- - _ -- - _ _ _ -- ----------------- KU 23X-06 --------------------- 159 ------- -- - 173 4,393 4.486 4.868 C-1 190 Calibrated gauge placed on well. KU 31-7X -- -- --- - - 162 - - -- - --•--••-- 176 ...... -_ 4,359 - ------ 4,446 ----------- 5.350 -------- ----- - -- C-1 C-2 --- — -- - 194 -_- _ - -- ------ - - - - - - -- Calibrated gauge placed on well. KU 33 -SAN — - - - - - 162 - -- - - -- -•-_........ . 176 ....__.__ - --- - 4,526 - - - - ---- - -- C-1 -_ — __ _ 194 __- ----_..—__ -- — -- -------------- Calibrated gauge placed on well. KU 33-7 161 •-._.... _.._...•-•• 176 ....... --_._.. 4.442 _._—. - 4,532 - - - - 5.050 - ------ -- - C-1 - --- - -- 193 - - - -----___... __ __ -------------- Calibrated gauge placed on well. ----------------- -- _ KU 34-31 -_ _------- 157 --•----- ------- ------------- 172 -----------•--••--•-- ----- - -- 4,653 -- -- - - -- 4 741 •- ........... . 4 743 - - ---- - - C-1 -- ---- -- 188 -- -—..._—._-- — — -- -- - - Calibrated gauge placed on well. KU 34-32L 160 175 4,485 4 580 5.239 C-1 191 BHP calculated based upon surface pressures KU 43-6RD AN 158 173 4,416 4.503 5,362 C-1 189 Calibrated gauge placed on well. KU 44-30L 156 170 41767 188 BHP calculated based upon surface pressures Pool 6 Shut -In Surface Pressures Date: Oct - Dec 2011 Wells had been Sit auorox. 48 hrs_ Well Test Gauge Psig Test Gauge Psia Mid -Pert TVDSS Mid -Peri TVD Mid -Pert MD Perforated Sand Cale'd MidPert (TVD) BHP psis COMMENTS KDU 5L 4 490 4,578 5 162 C-1 - KU 13 -SL ---------------- 151 ------------ 166 ------------------- 4.476 ------ 4.570 ------- 5123 ----------- C-1 ------------ 183 ---------------- BHP calculated based upon surface pressures ------------------------------------------------- KU 14-32 A 154 169 4,520 4,607 5;316 C-1 lee BHP calculated based upon surface pressures KU 14X-06 AN 158 173 4.403 4.498 4,498 C-1 .0-2 190 BHP calculated based upon surface pressures KU 21-6RD - 4,482 4.562 5,280 C-1 - KU 22-6X 160 175 4,537 191 BHP calculated based upon surface pressures KU 23X-06 159 174 4,393 4.486 4,868 C-1 191 BHP calculated based upon surface pressures KU 31-7X ---- -- - 158 -- -- - ------ 173 --------- -•-- - 4,359 - - -- 4,446 -- --_ 5,350 -- - - C-1. C-2 - - -- --- 190 - -- - - BHP calculated based upon surface pressures -- - - -- - -- -------- - -- - - KU 33-6AN - - 4.526 C-1 - KU 33-7 4,442 4,532 5.050 C-1 - BHP calculated based upon surface pressures KU 34-31 156 171 4,653 4 741 4.743 C-1 187 Calibrated gauge placed on well KU 34-32L 157 .— .,485 172 4F_ 4,580 5,239 C-1 lee Calibrated gauge placed on well. KU 43 6RD AN 162 177 4.416 4503 5,362 C-1 193 BHP calculated based upon surface pressures KU 44 30L - 4,767 - MarathonOil Exhibit 10:: Reservoir pressure distribution predicted by Eclipse simulation model ikl Exhibit 10:: Reservoir pressure distribution predicted by Eclipse simulation model 0 50 100 150 200 250 333 350 400 450 500 Tubing Pressure (psig) 23X-06 20.000 ----- -.-.T- --._.-.-- ---. - ' - - 1 I 1 - ------ - ---T-------- ----------- -__r,_______— ----.- --------- 1 1 1 I 1 • I I I I I I � I .05 is.DDD J________1________T________;________Y 7� r____ stfl________f__ - - - -- R 0.99 -----I I I I I I 14.003T-------J--------L-------- 1 -------- 1 I 1 I i 14;330 1 T- - - - - - - 1 L________________1________L_______1________L�______ J- - - - - - - -, I I I L_______ J ________ I 11r 12,330 _______'________r________!________Y________r_______T___ I ___r_______T________f_______ I I i I I I •~ Q 10,003 I T_______ I 1 I I 1 I J --------L -------- '-------- 1-------- �"------ Zf --------L-------J--------L------- I I I I I 1 � _ 8.330 I J_______________r________,--______+_-______� I 1 I I I I I • M - ______________ _______ ,� ____y________r_ I 1 1 I I L` 5,000 1I T________, I I 1 I I 1 r 1 f$ 8.000 1 I .. I I I I I I I N 4.003 1 i_______y________r_____-_-;______,_{�_______r_______y________ 1 ' I _______�________r_______ 1 I I 2,000I r_______J________L_______ 1 I 1 ____;"•__________________i________t_______!________________ �. I I ' I r 1 I I • 1 I I 4.330 J_------- a-------- ..-------- 1 1 I 1 t I I I I I r 1 I 0 50 100 150 200 250 333 350 400 450 500 Tubing Pressure (psig) 31-07X 20.000 ----- -.-.T- --._.-.-- ---. - ' - - 1 I 1 - ------ - ---T-------- ----------- -__r,_______— ----.- --------- 1 1 1 I 1 18A33I 1 ________L________I_-______1________L_______J________L-__-___JI________L_______J I I 15,33'0 I I I T______-1-___-___r________I I 1 1 1 I I I t I I I I I 1 -------- T-------- r------- T-------- f_______1_r_--___r------- 1 14.003T-------J--------L-------- 1 -------- 1 I 1 I L-------- �-------J--------- L -_-----J -------- LI --------I I 1 I 1 14.300 j --------J--------1 -------- --- 62.34x 62.34x -,648.23-L---�_-J--------L- .7 10.000T1_______J________I 1 1 1 1 - I R2= 0.99 1 1 12,000 +------- --------y-------- - -�- 10.000 1 1 1 1 --------- I 1 1 I '• I 1 -------=--------I ________._�__-i_______J________i_______- L` T______-_i_-------i__------L I 1 I I I 1 I I 1 r 1 f"j 8.000 1 I I '�_______y__-_____f__-__-__1-_______y-_______r____.�G_y________f_______y_-______f_______y +r 1 I 1+ I I i I I tir 1 I I I I 1 �+ i 1 1 1 1 5.003 I I I --------- --------L-------=--------=------- I I 1 +' 1 1 1 I 1 I I � I i ________I �'=------�--------' '--------L--------' �. I I I +• I I I I I I 4.330 J_------- a-------- ..-------- 1 1 I 1 t I ____-_-____-___ 1________-_--_____�------- J________F-------------------------- •+ i I ---- I 1 I I I I 1 1 I I 1 2,000 2.000 -r-------�--------r--------r-------t--------r-------�--------r-------�--------r-------- 1 1 I t I 1 1 I 1 7 1 t I 1 1 1 1 L I 0 L- 0 50 100 150 200 259 300 350 400 450 500 Tubing Pressure (psig) 21-06RD 20,000 1 I 1 I ---- , -�--------T--------1 1 I 1 I I I 18,300 T_______ I 1 I I 1 1 1 i 15.aaa 1 T --------I- I I ----------------------------- I 1 , 14.003T-------J--------L-------- 1 -------- 1 I 1 I L-------- �-------J--------- L -_-----J -------- LI --------I I 1 I 1 12,030i_______ 1 -1________r -------- I________Y________r_______-________r----------------- 1 I 1 r________ I I 1 1 I, 10.000T1_______J________I _______JI ________ I_______J1________L1 ________ .x -, . I, I 2= R 0.98 8.000 y--------�--------*--------I--------* 1 ---r--------1----------------- 1 I I 1 I I � m 5.300T-------J--------L-__----J--- 1 I I I I -Jb L---L-------J_�=_----L-------J--------L-------- I -Ir: '' I I I I /y m 1 I I I - , I I r-- I I 4.000 1--------+--------y--------1----------------��=------y--------f------- I I -------- - 1 I 1 i s _- IS 1 I I 1 -------- I 1 ------------------ --------------------------------------------------------------- I I I I I I � I I r 0 50 100 150 200 250 300 350 400 450 500 Tubing Pressue(psig) Marathon Oil Allocation Ratio Total Gas Total Gas 'Native Gas ' Stored Gas Native Stored Date Injected Withdrawn Gas Gas Withdrawn Withdra•::n ............. Jan -10 ..........................•... 86,156 424,9B6 ------------............................ 60% 40% ---------------- 254,992 -----..--.............. ------............--- 169,994 ................ Feb-10 ...... 100.523266.910 .............................................. 60% .....•.......... 40% ----.................................... 160.146 ------........... . ............................................... Mar -10 20.025 432.777 .................... ......................................................... 60% 40% 259.666 ............... 173111 n....... Apr -10 ............................................................................................................. 1.143,288 60% 40% 685.973 457 - 1 e,1ay-10 26.534 189,512 ...................................... 50% 50% ........................................ 94.756 ....................... 94 -= --------- Jun -10 -------- 76,2247 ----------------------- 124,199 ----------------------- 50% ---------------- 50% ---------------- 62.100 ----------------------- ..................... 62.1:0 i ........................................................................................ JL11-10 371,521 32.75050% 50% ....................................... 16,375 ....................... 16,375 .............................................................................................................................. Aug -10 33.282329.282 50% 50% 164,641 ....................................... 164,641 ----•- ....................... Sep-10903.271 .............................................. 50% •--------•--......--........................................----..........------ 50% 451,636 451,636 .......-• 010-10 ...................................• 929,929 ------------......-•--- 50% -----------.....................-..............------...............--.....••--- 50% 464,965464,965 NOV-10 ........................................................ 949,205 50% 50% ................................................ 474,603 474,603 Dec -10 70 1.275.074 50% 50% 637.537 637,537 .............................................. Jan -1111,014 1.145.922 ........................................................................................................ 50% 50% 572,961 572.961 -------------- Feb -11301 -------- --------------------•- 948,685 ........................................ 50% 50% ................ 474,343 ---------...........-- ---------------------- 474,343 ........................................................................................ Mar -11 172.460439.687 50% 50% ................. 219,844 ........................ 219,844 ................................................ Apr -11 14,656417,494 -----................................... 50% 50% 208,747 208,747 ....................... h4ay-11115.641 ................................ 240,164 50% 50% 120,082 120.082 .............................................. Jun -11452,435 26.121 ............................................................ 50% 50% 13,061 13,061 ...................................................................................................................................................... Jul -11474.008 40,322 50% 50% 20,161 20,161 ...................................................................................................................................................... Aug -11 277,49826.025 50% 50% 13.013 13,013 Sep -11 28.606 ................................................................... 292,762 50% 50%146.381 .............................................. 146.381 ....................................................................................................... Oct -11287,672 105.348 50% 50% 52,674 .............................................. 52.674 14OV-11 58.372 ............................................... 536,982 50% ...... 50% ........... . . . .... 268,491 ................... 268,491 Dec -11 1 09. 221 292.186 50% 50% 146.093 146,093 2009 Total 714,353 7.001,183 3,727,388 3.273,793 2010 Total 2.001,884 4,511.698 2.255.849 2,255,849 Kenai- Sterling Pool -Average Daily Rates (2010 - 2011) 50 -7 — - - ■ Withdrawn Gas -RFcfc — 7� 1 ■ Injected Gas - N1dd 44 30 20 CU C 10 0 C? -10 -20 — � O ,n 2 ❑ ¢ � n Z Marathon Oil 300,0 '\ • 2006 02007 02008 O 2009 ®2010 •2011 Official P.2♦ \ 250.0 O �i 200.0 a N 150.0 i. a \ 1 100.0 \ ♦ \ \ \ � ♦ y y i 50.0 0.0 5.10E�08 5.20E-08 5.30E+08 5.40E+08 5.50E=08 5.60E-08 5.70E-08 5.80E_ 08 Cum. Withdraw (MCF) li'`Q;.II Marathon Oil '\ O 2009 ®2010 •2011 Official P.2♦ \ \ \ O �i r \ i. \ 1 \ ♦ \ \ \ � ♦ y y i li'`Q;.II Marathon Oil Black - Monthly averaged gas injection rates Red - Monthly averaged gas production rates Blue - Monthly averaged field pressures MarathonOil Monthly Rates Pressures ""—Monthly Average Average Gas Production Rates and —Monthly Average Gas Injection Rates —Monthly Average Field Pressures 60000 y,�Q 50000 40060 _ _. - -- _. 200 J0000 3 2000-0 100 n •o 2 a 10000 0 Q -- 1 1/1/Q7 1/1/08 1/1/09 1/1/10 1/1/1, 1/1/12 041E Black - Monthly averaged gas injection rates Red - Monthly averaged gas production rates Blue - Monthly averaged field pressures MarathonOil