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Home My WebLink About2013 Nicolai CreekAurora Gas, LLC www.aurorapower.com July 30, 2014 Ms. Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7a' Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED AUG 0 4 2014 AOGCC RE: Reservoir Surveillance Report and Reservoir Pressure Reports (Form 10-412) Aurora Gas, LLC: Nicolai Creek -South Undesignated and -Beluga Dear Commissioner Foerster: Aurora Gas, LLC hereby submits a Reservoir Surveillance Report and four Reservoir Pressure Reports for the pressures taken in 2013 at Nicolai Creek Unit No. 113, No. 2, No. 9, and No. 11 gas production wells in the Nicolai Creek Gas Field on the west side of Cook Inlet, as required by Conservation Order No. 478A. Please find enclosed the following information for your files: 1) Reservoir Surveillance Report (Combined for NCU- South and NCU- Beluga) for 2013; 2) Form 10-412 Reservoir Pressure Reports for Nicolai Creek -South Undesignated for 2013; 3) Form 10-412 Reservoir Pressure Reports for Nicolai Creek -Beluga for 2013; 4) Nicolai Creek Unit Pressure Map, showing pressures for 2013; and 5) Supporting information: P/Z vs, Cumulative Production Plots for #1B, #2, #9 (3), and #11 (2). If you have any questions or require additional information, please contact me at (281) 495-9957 by email at i6ones aaurorapoweiwom. . Sincerely, AU OL S, LLC . Edwes President enclosures cc: Temple Davidson and Kevin Pike, ADNR-DOG 4645 Sweetwater Blvd., Suite 200 • Sugar Land, Texas 77479 - (281) 495-9957 • Fax (281) 495-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 NICOLAI CREEK UNIT WELLS NO. 113, 2, 9, and 11 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A HISTORY AND SUMMARY AS OF 12/31/13 BACKGROUND Aurora Gas, LLC re-entered and side-tracked the abandoned Texaco Nicolai Creek Unit (NCU) No. 1A in 2002 and completed the well in three Upper Tyonek sands, the Carya 2-4.2 at 3137-3157' TVD, the Carya 2-5.1 at 3307-3348' TVD, and the Carya 2-6.1 at 3506-3521' TVD. These intervals were commingled upon completion and tested with an AOF of 3.1 MMCfpd. Unfortunately, in spite of free -hanging sand control screens in the completion string, the well produced water and sand along with the gas, and, consequently, produced very little gas for sales to date. Unable to control the sand production by surface means, the well was recompleted in June of 2006: 1) plugging off the Carya 2-6 sand, from which the sand and much of the water was being produced (as evidenced by sand fill and a "sand -blasted" hole in the screen at that depth), 2) adding perforations to the Carya 2-3 sands at 2783-2864' TVD, the Carya 2-2.2 sands at 2550- 2568' TVD, the Carya 2-2.1 sands at 2426-2434' TVD, and the Carya 2-1.2 sands at 2254-2316' TVD, and 3) completing selectively (see attached well bore diagram). As of December 2006, the Carya 2-3 to the Carya 2-1.2 sands were mechanically open and producing (perfs at 2307-2918' MD), and the deeper sands, 2-4 to 2-5 (perfs at 3191- 3401' MD) were opened in October 2010 following a chemical sand control treatment. All these perfs are open have been producing since, with some sand possibly covering some of the lower perfs. However, the well has produced 397.2 MMcf through 12/31/13, most of which has come from the upper completions. The NCU No. 2 well was also re-entered by Aurora Gas in 2002 and re - completed into the Upper Tyonek Carya 2-1.1 sand at 2141-2177' TVD, the Carya 2-1.2 sand at 2342-2354', and the Carya 2-2.1 sand at 2493-2511' TVD. These commingled intervals tested for a calculated AOF potential of 14.6 MMcfpd. A production facility and gathering line were constructed in 2003 and the well started producing to sales December 2003. The well was recompleted in September- October of 2013 with a selective completion, going back to the original (Texaco) zone, the Carya 2-2.3 at 3268- 88' and 3324-36' MD and opening new zones, the Carya 2-1.0 at 2312-22' MD and the Lower Beluga at 2198-2212' and 2244-60'. The shallower two zones were commingled but not put on production until a Commingling -Spacing Order was approved early in 2014. The well has produced 803.5 MMcf since the re-entry thru 12/31/13. The NCU No. 9 was drilled on the same pad as the two directional wells above in 2003 to capture reserves behind two strings of pipe in the two old wells. It was completed in a Beluga Tsuga 2-7 interval at 1320-1447' TVD/MD (now the Middle Completion). This well tested yielding at calculated AOF potential of 49.1 MMcfpd. It also started producing to sales in December 2003. Because this completion had depleted significantly, a recompletion adding additional Tsuga 2-8, 2-7, and 2-6 sands from 1148- 1904' was completed in September 2006. The well produced 326 MMcf from the Lower Completion at 1552-1904' (9 different Tsuga 2-7 and 2-8 sands) between the recompletion in October 2006 and October 2008. In October 2008, the pressure of this Lower Completion had declined to near that of the Middle Completion, so the sliding sleeves for the Middle Completion were opened, allowing both the Middle and Lower Completions to produce commingled. In August 2012, these two lower producing intervals were closed off, and the Upper Completion, Beluga Tsuga 2-6, was opened to production. On January 31, 2013, al zones were opened to commingle production as pressures were nearly equalized. The well has produced a total of 2537.7 MMcf (2.5 BCF) thru 12/31/13, of which 551.0 MMcf is allocated to the Lower Completion, 1762.9 MMcf to the Middle Completion, and 223.9 MMcf to the Upper Completion. NOTE: All three of the above well are on the same pad, with the #IB and #2 being directional, so all have the same ground level elevation (22' AMSL) and nearly the same KB/DF elevation, so TVD's are very nearly TVDss and, thus, almost directly correlative. NCU #11—The Nicolai Creek Unit #I 1 well was drilled in September 2009 to a depth of 3600' (MD/TVD) and was completed on October 6, 2009, in 14 Beluga sands and 2 Upper Tyonek sands isolated by packers and sliding sleeves into 4 selective completions. The well was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260- 2362'. These commingled intervals were tested (4 -point) to give an CAOF of 5466 mcfpd with a static pressure of 924 psia (909 psig) at a datum of 2049' TVD (-2033' TVD SS). Production was initiated from the Tyonek Carya 2-1 completion in December 2009, and the well produced 11,281 mcf that month. Following commingling approval, the well produced from the Beluga and Tyonek perfs at 1736-23621, sometimes selectively, sometimes commingled. Two shallower selective completions were briefly tested upon completion and are thought to be productive, but were not produced until the Upper Middle Completion (Beluga Tsuga 2-6 with perfs between 1349- and 1675') was opened in September 2011. (The Upper Completion, Beluga Tsuga 2-5 and 2-6 with perfs at 920-1216', was tested in early 2013 and found to produced water with sand, so it has not produced to sales). The Upper Middle Completion has produced most of the time since being opened, sometimes commingled production with the Lower (Tyonek) Completion. The Lower Completion makes sand and fill has been cleaned out with coiled tubing twice, in June of 2011 and in 2013. The production when commingled is allocated back to each zone on the basis of production tests when each zone is producing by itself. The well produced 1043.2 MMcf through 12/31/2013: 321.6 MMcf allocated to the Upper Middle Completion, 491.2 MMcf allocated to the Lower Middle (Beluga) Completion and 230.4 MMcf allocated to the Lower (Tyonek) Completion. CONSERVATION ORDER NO. 478A REQUIREMENTS This Order issued October 16, 2003, by the AOGCC has three items pertaining to reservoir surveillance at Nicolai Creek Unit wells No. 113, No. 2, and No.9, requiring: 1) (#3) Initial reservoir pressures, 2) (#4) Annual monitoring of reservoir pressures, and 3) (#5) Annual reservoir surveillance reports. INITIAL RESERVOIR PRESSURES Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2002 and 2003, show initial reservoir pressures. The initial reservoir pressures for #1B and #2 were obtained by bottom -hole pressure surveys (No. 1B and 2) and confirmed by quartz -crystal surface pressures extrapolated to subsea datum. These initial pressures were: #1B-1625 psig at -3293' TVDss, and #2-1025 psig at -2285' TVDss. The #9 well was taken by quartz -crystal surface pressure recorder and was confirmed by open -hole MDT measurements—it was 673 psig at -1348' TVDss. Subsequent work, i.e., the 2006 recompletions of #1B and #9, added the following original pressures: #1 B-1211 psig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 2480'- 2918' MD) and in #9-666 psig at -1706' TVDss (Lower Completion). The drilling of the #11 well in 2009 gave additional pressure information: it was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260-2362' with a static pressure of 924 psia (909 psig) at a datum of 2049' TVD (-2033' TVD SS). ANNUAL MONITORING OF RESERVOIR PRESSURES Attached are Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2013, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and #9, which have made very little water, so they are consistently in single-phase condition. Surface pressures in #1B and #11 may be affected by some minor buildup of water in the wellbore, but no bottom -hole pressures were obtained in 2013. Note that due to the recompletions of #1B and #9 in 2006 and the subsequent production of different intervals, the datum TVDss's for these wells have changed since the 2006 submittals. Note also that the #11 well is included in these 10-412 reports although it is in an different PA (West the Lower Middle (Beluga) completion is included in the Beluga Pool report and the Lower (Tyonek) Completion is included with the South Undesignated Pool. The reservoir pressure survey data and production data from the four producing wells have been plotted to yield P/Z vs. Cumulative Production curves, providing a material - balance projection of reserves. Those plots (using Ryder Scott Excel templates) are attached—there are seven.. These show the #113 having an EUR of 654 MMcf from commingled from all the perfs, of which 397 MMcf were produced thru 12/31/13. The #2 is shown to have an EUR of 1069 MMcf, from the original Aurora Gas completion, of which 803 MMcf had produced thru 12/31/13—however, no additional reserves are expected to be recovered from these perfs due to sub -commercial production. With the recompletion, volumetric reserves of about 200 MMcf are expected. The Middle Completion of the #9 is given an EUR of 2063 MMcf, of which 1763 MMcf had produced thru 12/31/13—this interval is now commingled with the Lower Completion, which is shown to have an EUR of 628 MMcf, of which 551 MMcf were produced thru 12/31/13, and with the Upper Completion, with an EUR of 311 MMcf of which 224 MMcf have produced. The commingled Lower (Tyonek) and Lower Middle (Beluga) completions in the #11 are shown to have an EUR of 976 MMcf by the P/Z plot, of which 722 MMcf were produced thru 12/31/13. The Upper Middle Completion in #11 has an EUR of 686 MMcf of which 322 MMcf has produced thru 12/31/13. The recompletion of the NCU #1B in June 2006 provided additional pressure information of some of the Upper Tyonek Carya sands that have been producing in the #2 well. This pressure data from the tests indicates that there is no depletion of these zones in the No. 1 B from the No. 2 production. In particular, the Carya 2-1.1, 2-1.2, and 2-2.1 are commingled in the #2 and had an initial SIBBP at -2285' TVDss of 1025 psig. The comparable zones in the #1B, commingled 2-2.1 and 2-2.2 and the 2-1.2 had bottom -hole SIP'S estimated at 1045 and 1040 psig at datum of -2484' and -2272' TVDss, both are close to the original pressure in #2 and much higher than the then most recent SIBHP's of 293 psig at -2285'. This indicates that there is a geological barrier and no communication between the two well bores. POOL PRODUCTION ALLOCATION FACTORS The production from NCU 1B, 2, 9, and 11 is metered several times and allocated back to each well on the basis of these meters. Each of the three wells has an individual separator into which the well flows, eliminating any free water from the flow stream, then immediately downstream of the separators, each well is individually metered. The flow from the three wells may be combined at this point and then compressed before going thm the glycol dehydration system. (Booster compression has been added, so the lower pressured wells can be selectively compressed before going to the main compressor). After dehydration, the combined flow from these three wells is metered again before going into the gathering system. The gathering system takes the gas to the CIGGS Meter 6103/8103 where it is joined by the flow from NCU #3 and 410 upstream of the sales meter. It is metered before being commingled into flow going into the Marathon - operated CIGGS pipeline system. The total sales volume through this meter is allocated back to each well proportionally based on the individual well meter volume divided by the sum of all the wells meters' volumes minus lease -use gas, where lease -use (fuel) gas is allocated proportionately to each well at a facility. RESERVOIR DEVELOPMENT AND DEPLETION PLANS NCU 113—This deeper intervals in this well were treated with the Weatherford chemical "Sand Aid" in 2011, and the Upper completions (Carya 2-1 thru 2-3) were treated with Sand Aid in October of 2012. These treatments seemed to remedy the sand production, reduced the water production, but may have hurt gas production. The well produced 20 MMcf in 2013, producing intermittently. It was producing about 125 mcfpd in December 2013. No additional work is planned in this well. NCU #2—This well is sometimes produced with a booster compressor, giving it 3 stages of compression, but at this point is hasn't increased the rate significantly. It produced only 13.9 MMcf in 2013, but the recompletion into the shallower Beluga and Carya 2-1.0 have increased the production—it produced 260 mcfpd in June 2014. NCU #9—This well produced from the commingled Upper, Lower, and Middle completions when pressures equalized in early 2013, by opening the sliding sleeve isolating those perfs. This well produced 162 MMcf in 2013. It produced about 325 mcfpd thm the booster compressor in December 2013. Following the 2006 recompletion workover, this well bore still has 8 potential Beluga Tsuga 2-5 and 2-6 sands between 668' and 1054' that have apparent gas production potential. These sands were not completed at the time of the 2006 recompletion workover for 2 reasons: 1) the large pressure differential expected between these shallow sands and the deeper ones, and 2) the cement bond log indicates a top of cement at 840', so remedial cementing will be required for the shallower sand completions. Thus, at least one more recompletion workover is expected in the life of this well bore. This wellbore is also being considered for gas storage (Middle Completion, which is a high-quality reservoir) and would give an additional 2 BCF capacity to a storage project. NCU #11—This well has 4 completions, which were be opened selectively and produced as needed to meet market demand. However, the Upper Completion produced sand and water when opened in January 2013. The Upper Middle Completion, however, was opened in September 201 land has produced through April 2013,when the Lower (Tyonek) Completion was cleaned out The Lower Completion produces sand with small volumes of water and was cleaned out with coiled tubing in 2011, early 2012, and April 2013, but sanded off again by October. At that time, a tubing leak was found, allowing the Upper Middle completion to be producing (and believed to be the source of much of the sand fill) --a tubing patch was run across it in early 2014. Much of the production in 2013 came from the Lower Middle completion, found to be open in October 2013 and left open. This well produced 122 MMcf in 2013, currently making 100-200 mcfpd. The well will be cleaned out again with coiled tubing in 2014. Depending upon market demand and storage development, a shallow development well on the 1-2-9 pad may be drilled to recover the shallower reserves in the #9 well, both those in the Upper Completion and the shallower undeveloped sands. This would facilitate the use of the very good quality Middle Completion reservoirs for storage and would eliminate the need for an expensive recompletion workover to access the shallowest reserves. Beyond the above mentioned development, no additional development of either Pool is anticipated, as the Pools (and PA's) are now outlined. RESERVOIR PRESSURE MAP AT DATUM Because each well had its individual reservoirs, a reservoir pressure map at datum seems to be irrelevant. However, now that there are some common sands open in the #1B, #2, and #11 it may have more relevance, although the sands are apparently not continuous between wells. Attached is a pressure maps of the Nicolai Creek --South Undesignated Pool and the Nicolai Creek—Beluga Pool, showing initial and current pressures at the several pertinent subsea Data. Ed Jones (7/29/14) > V E n � ❑ m N M M m M N j �n E `o v v E c E - m o❑ m O h ° N� 2 N co Z ~ N v N N 2N o E_ N 3 3 LL O N ❑ O N N m O d p � � 10 m O fi O O_ ri v � n p.❑ " v❑�� N n N N U 3 V U a o O 'm m a r ❑ (O a - IL h a m � O W m '� E o 0 o E �a8 a a a 3 a a o x x x O_ Wu In LL N / Q (n LLu Z c Z �h- N y m W V a � N d a 00 g a o M W U ^ F 0 v N M y s < U) - CD y M N cn aD p d E c6 m m Z a O '^ x J N d N❑ Ti L L N N m N 0 N N � 'p N O ,J Z Q ^ m m } N N o N o 3 a U) WN Y O O Y Y d U Y N O J oN O IE � OO O c d � c o d 2 o _ F W W r r r r t m 3 ❑ E � v ❑ ° umi m umi umi m '�° V y J y U O ts m p 3 0 o O 3 O y d N v E N N d M m u E ✓ ZUI ¢ ❑ O o n O O O O o n a o « a a ¢ O .° Z c M M a Z d M Z t v 3° 3 o a o o O O a o O Z m N O O Zzi v Q W WE � o O U Z E m u O z m n 7 00 � Q O m U U U r D m Z m Z ru go I NJ) \��\/ O §a : ! 0 LU .! t ° ■ !/ ;«,!! . § w [ - /\5~�!®\ j J2 (j) 5 cc@ ] \ LIL { \§w /\ _ 2/a - ~ U) \ \ \ }!k§ \ P. \ \ \ ow- . . \ Uj ` \ \ \!CO \ \ \ \ \\ § \ \ ; \\\\� WELL NAME: NICOLAI CREEK UNIT #11B SOUR GAS Ryder Scott F� _ FIELD: NICOLAI CREEK 3.29 Reservoir rb.� COUNTY, STATE: KENAI PEN. BOR.(WEST SIDE OF COOK INLET), ALASKA TVD, FEET: Solutions -y RESERVOIR: COMMINGLED CARYA 2-1.2 TO 2-3 (2307-2918') (Public) 6620W 7-AA7 rnrrertinn for contaminants. if anv (Protected) 0.8755 WELLHEAD TEMP, *F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, *F: 80.0 N= 3.29 WET GAS GRAVITY: 0.572 CO, 0.30 TVD, FEET: 2,476 H,S 0.00 COND. CORR? (YIN): N Corrected* Tc,*R: 340.81 Corrected* Pc, Psia: 667.76 1,400 1,200 1,000 w 800 N (L N a M 600 400 200 MMCF 0 0 100 200 300 400 500 600 700 800 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMd LSMF Include? (Y/N) 1 6620W 1,038 1,102 0.8755 1,258 0 n 2 2/10/2007 575 608 _ 0.9268 656 _95 y 3 5/19/2007 515 544 0.9341 583 159 y 4 6/1212005 535 565 0.9317 607 175 Y 5 8/6/2007 363 383 0.9530 402 _ _ 225 n 6 9/12/2007 438 0.9465 463 226 y 7 9/12/2007 392 413 0.9494 435 226 n 8 12/1/2007 315 332 0.9591 346 256 _ n 9 5/29/2008 345 364 0.9554 381 _ 261 Y _ 10 _ 5/21/2009 3281 346 0.9574 361 282 Y 11 8/15/2010 335 353 0.9566 370 _ 290 Y 12 10/15/2010 535 565 0.9317 607 290 _ Y_ 13 2/4/2011 375 396 0.9515 416 320 y 14 10/1/2011 365 385 0.9528 404 328 Y 15 10/31/ 012 285 301 0.9629 312 373 N 16 1/21/2013 8/11/2013 320 360 338 3801 0.9585 0.9534 352 399 _381 386 N Y 17 Point 6 is from bhp survey—however, sand in tubing above lower pe Point 7 is from surface pressure at the time of the BHP survey for Point 6. Water in well bore? _ These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT NO. 2 Solutions FIELD: NICOLAI CREEK I BHP/Z, Psia COUNTY, STATE: T11N, R12W SM, Kenai Borough, West Side Cool RESERVOIR: Upper Tyonek, 2426-2916' MD 1,073 1,058 _ 1,060 807 ' WicheR-ANz correction for contaminants, if any --- 1,230 1,211, 1,214 896 WELLHEAD TEMP, aF: 45.0 SOUR GAS MOLE % BOTTOMHOLETEMP,'F: 77.0 Nz 1.06 WET GAS GRAVITY: 0.5607 CO, 0.00 TVD, FEET: 2,309 --HS 0.00 COND. CORR? (YIN): Corrected' Tc. °R: N 343.70 0.9213 1,400 1,200 1.000 A 800 Z N 'o. m 600 400 200 Reservoir rp.� Solutions I BHP, Psia (Public) I BHP/Z, Psia 'Pmtectedl -.-- MMCF 0 — 0 200 400 600 800 1,000 1,200 1,400 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia I BHP, Psia =LMF pati o6tl.OW aEVR=1,111 apGp=1.185 I BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 2 3 4 11/21/2003 11/22/2003 11/22/2003 2/11/2004 1,016 1,002 1,004 76_6 1,073 1,058 _ 1,060 807 0.8721 0.8736 0.8734 0.9004 --- 1,230 1,211, 1,214 896 0 2 2 142 n--- n -- N y 5 6/15/2004 555 _ 584 0.9264 630 267 N 6 O 595 626 0.9213 680 270 y 7 12/31/2004 385 404 0.9483 427 461 n o « 395 415 0.9470 438 470 n 0 _ 7/16/2005 415 436 0 — 0 200 400 600 800 1,000 1,200 1,400 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia I BHP, Psia I Z I BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 2 3 4 11/21/2003 11/22/2003 11/22/2003 2/11/2004 1,016 1,002 1,004 76_6 1,073 1,058 _ 1,060 807 0.8721 0.8736 0.8734 0.9004 --- 1,230 1,211, 1,214 896 0 2 2 142 n--- n -- N y 5 6/15/2004 555 _ 584 0.9264 630 267 N 6 7/15/2004 595 626 0.9213 680 270 y 7 12/31/2004 385 404 0.9483 427 461 n 8 4/30/2005 395 415 0.9470 438 470 n 9 _ 7/16/2005 415 436 0.9444 462 472 y 10 2/17/2006 225 236 0.9695 244 554 n . 11 9/14/2006 168 176 0.9772---- 180 609 n 12 10/3/2006 195 204 0.9736 210 609 N 13 12/31/2006 240 252 0.9675 _ ---260 624 N 14 1/18/2007 255 268 0.9655 277 624 N_ 15 2/4!2007 275 289 0.9629 300 624 n 16 3/8/2007 300 315 0.9595 328 624 Y 17 4/9/20030/2007 _ _ 295 310 0.9602 323 630 Y 18 8/11/2007 287 301 0.9613 313 647 Y 19 5!28 124 130 0.9832 132 712 n 20 1/31/2009 255 268 0.9655 277 729 Y These results were prepared using Ryder Scott's Gas Materfal Balance. This is not Ryder Scott work product. POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP Z' Psis CUM PROD, MMcf LSMF Include? (YIN) 21 5/21/2009 243 255 0.9671 264 _ 738 y 22 9/1/2009_ 300 315 0.9595 328 739 Y 23 1/31/2010 250 262 0.9662 272 750 n 24 11/30/2010 293 308 0.9605 320 765 Y 25 513112011 320 336 0.9569 351 772 Y 26 _ 11/25/2011 315 331 0.9575 345 779 Y 27 10/31/2012 360 378 0.9516 397 787 Y 28 8/25/2014 370 389 0.9503 409 796 Y Points 1 & 2 were measured by testers before and after 4 -point test. Point 3 was measured with crystal recorder after 4 -point test and buildup. Point 4 was measured with crystal recorder when SI for dehy problems. Points 5 & 6 were from tree gauge. Point 7 was from tree gauge after long SI (4/1/05). Point 12 was measured by Pollard SPIDR after long term SI. Points 13-17 are long-term SIP's from tree gauge—well continues to build up over time. Point 18 is SIP from SPIDR—SI about 45 hrs—still bldg Point 19 is from SPIDR but not long term buildup -8 days vs weeks with other points Point 20 is long term SIP from tubing gauge Point 21 is LT SIP wl SPIDR Point 22 is LT SIP from tree gauge These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT #9 _ FIELD: NICOLAI CREEK COUNTY, STATE: _ KENAI PEN. BOR., (WEST SIDE OF COOK INLET), ALASKA RESERVOIR: BELUGA (TSUGA 2-6) PERFS AT 1148-1264' (UPPER COMPL) ' Wichert-Aziz correction for contaminants, if any WELLHEAD TEMP, "F: 40.0 SOUR GAS MOLE % 572 555 241 169 190 BOTTOMHOLE TEMP, °F: 66.0 Nz _ 0.87 N Y Y n y WET GAS GRAVITY: 0.562 CO, _ 0.33 TVD, FEET: 1,206 _ _ HzS 0.00 COND. CORR? (YIN): N _ Corrected* Tc, °R: 343.56 Corrected* Pc. Psia: 672.16 700 600 500 m 400 m a. N i2 m 300 200 100 Ryder Neon [[ Reservoir Solutions (Public) Y -Intercept, BHP/z 572 _ OGIP, MMCF _ 334 EUR, MMCF 311 Recovery Factor 0.9299 BHPIz (a) Abandonment 39 0 . . _.._ _ _ ,. _-__-.._.._.....-............ — 0 50 100 150 200 250 300 350 400 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (YIN) 1 2 3 4 5 9/15/2003 9/15/2006 1/31/2013 8/25/2013 6/12/2014 540 2351 165 185', 572 555 241 169 190 0.9224. 0.9247 0.96_67 0.9766 0.9738 620 600 249 173 195 0 0 147 201 245. N Y Y n y Point 1 is XPT These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. ELL NAME: NICOLAI CREEK UNIT NO. 9 SOUR GAS Ryder Scott a3 FIELD: NICOLA] CREEK Ni Reservoir TY, STATE: TI IN, R12W SM, Kenai Borough. West Side Cook Intel, Alaska CO2 Solutions 1 ESERVOIR: Beluga 1320-144T (MIDDLE COMPLETION) H2S (Public) correction for contaminants. if am !Protected) J WELLHEAD TEMP ,'F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP,'F: 66.0 Ni 0.89 WET GAS GRAVITY: 0.5633 CO2 0.35 ND, FEET: 1,384 H2S 0.00 COND. CORR7 (YIN): N Connected" Tc, °R: 343.86 Corrected' Pc, Palo: 672.10 800 700 600 500 T ,i400 m 300 200 100 0 0 183 MMCF ren Factor 500 1,000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) r DATEBHP/Z, (Optional) SITP, Psia BHP, Pais Z Pais CUM PROD, MMot LSMF In Jude? (Y/N) 1 9/22/2003 O 0.9086 745 0 n 2 11/20/2003 667 688 0.9072 759 0 y O � _ 2/11/2004 586__ 605 0.9179 O p 4 6/18/2004 515 531 0.9275 573 310 500 1,000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) r DATEBHP/Z, (Optional) SITP, Psia BHP, Pais Z Pais CUM PROD, MMot LSMF In Jude? (Y/N) 1 9/22/2003 677 0.9086 745 0 n 2 11/20/2003 667 688 0.9072 759 0 y 3 _ 2/11/2004 586__ 605 0.9179 659 108 y 4 6/18/2004 515 531 0.9275 573 310 y 5 12/31/2004 405 417 0.9427 443 666 n 6 4/30/2005 420 433 0.9406 _ 460 680 n 7 7/16/2005 435 448 0.9385 478 682 Y 8 2/17/2006 325 335 0.9538 351 864_ Y 9 9/12/2006 173 179 0.9752 1831 1,068 n 10 5/21/2009 220 227 0.9686 234 1,228 n 11 127/4/2010 13 14 15 16 17 18 9/2/2009 9/21/2010 8/8/2011 8/27/2012--— 1/31/2013 8/25/2013 6/12/2014 255 235 205 184 110 195 1651 185 2631 _ 2421 211 189 113 201 170 191 0.9637 0.9665 0.9708. 0.9737 0.9843 0.9722 0.9764 0.9736 _ 273 1,228 250_ 1,392 217 1,453 195 1,532 115 1,697 207 1,697 1741 _ 1,7441 196779 Y Y y _ _y y y _ n y Point 1 is bhp from open -hole MDT. Point 2 is surface pressure measured by testers before 4 -point test. Poiint 3 is surface pressure from crystal pressure recorder. Point 4 is gauge pressure. Points 5, 6, and 7 is tree gauge pressure after long -tens SI (4/l/05) Point 8 is tree gauge pressure after 28 hr SI Point 9 is short -time shut in just before recomple0on—not likely built up to static. These results were prepared using Ryder Scoft's Gas Material Balance. This is no Ryder Scott work product WELL NAME: NICOLAI CREEK UNIT #9 FIELD: NICOLAI CREEK CO_ LINTY, STATE: KENAI PEN. BOR., (WEST SIDE OF CO( RESERVOIR: BELUGA (TSUGA 2-7 8 2-8) PERFS AT 1 Wirhert-Aziz corraction for contaminants. if anv WELLHEAD TEMP, "F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, °F: 74.0 NZ 0.87 WET GAS GRAVITY: 0.562 CO= 0.33 TVD, FEET: 1,728 HSS 0.00 GOND. WKWe (Y/N): N Corrected' Tc, "R: 3_43.56 Corrected' Pc, Pala: 672.16 1,000 900 600 700 600 BI y 0 H 500 'o. x ro 400 300 200 100 0 0 tyaer acort F: Reservoir 'r. Solutions .L MFS. eEyq, Da •EUR.RB .=P=B]5 (Public) LSMF Include? (YIN) IPmtertedl MMCF MMCF 100 200 300 400 500 600 700 800 Cumulative Production, MMef POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z .L MFS. eEyq, Da •EUR.RB .=P=B]5 CUM PROD, MMCf LSMF Include? (YIN) 739 480 1 9/26/2006 650 676 0.9139 2 y 2 2/10/2007 435 452 0.9414 94 n 3 5/1/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 _ 493 0.9362 527 159 y O O 637 0.9186 693 163 n 6 9/25/2003 810 _ 0.8981 902 0 n 7 8/11/2007 O ♦ 0.9475 426 163 n 8 11/6/2007 385 400 O 422 208 n 9 5/29/2008 351 365 0.9525 383 271 100 200 300 400 500 600 700 800 Cumulative Production, MMef POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMCf LSMF Include? (YIN) 739 480 1 9/26/2006 650 676 0.9139 2 y 2 2/10/2007 435 452 0.9414 94 n 3 5/1/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 _ 493 0.9362 527 159 y _ 5 8/11/2007 637 0.9186 693 163 n 6 9/25/2003 810 _ 0.8981 902 0 n 7 8/11/2007 389 404 0.9475 426 163 n 8 11/6/2007 385 400 0.9480 422 208 n 9 5/29/2008 351 365 0.9525 383 271 Y 10 10/13/2008 260 _ 270 0.9647 280 325 Y 11 5/7/2009 215 _ 223 0.9707 230 385 n 12 13 5/21/2009 9/2/2009 220 255 228 _265 0.9701 235 385 n 0.9653 _ 274 385 Y 14 7/4/2010 _ 235 244 0.9680 _ _ 252 _ _ 413 Y 15 9/21/2010 205 213 0.9721 219 434 Y 16 8/8/2011 184 191 0.9749 196 460 Y _ 17 8/27/2012 110 114 0.98501 1161 5351 Y 18 195 202 0.9734 208 _5_35_ 5451 y n _1/31/2013 19 8/25/2013 165 171 0.9775 175 20 6/12/2014 185 192 0.97481 1971 5561 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. NICOLAI COUNTY, STATE: KENAI PENINSULA BOR., ALASKA RESERVOIR: L Tsuga 2-7 & 2-8 + Carya 2-1.1 & 2 f Ate:.—r—finn fnr rnnfamirnnfe if Anv WELLHEAD TEMP, °F: 50.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, "F: 87.0 Nz 1.00 WET GAS GRAVITY: 0.562 CO, 0.00 TVD, FEET: 2,049 H,S 0.00 GUNU. GUKKr (TINI: N Corrected' Te, "R: 344.25 Corrected* Pc, Psia: 671.89 1,200 1,000 800 m y a N 600 a x m 400 200 0 0 Ryder Scott rt -3 Reservoir r? Solutions5.0 (Public) /DrninrfcHl MMCF 0.9267 200 400 600 800 1,000 1,200 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional)SITP, Psia I BHP, Psia ♦LSMF Data o Excluded Data BHP/Z, Psia CUM PROD, MMd LSMF Include? (Y/N) 1 2 3 • EUR = 976 ♦OGIP = 1,053 881 585, 595 923 612 622 0.8946 0.9276 0.9264 1,032 659 672 __ 0 282 293 Y Y O 4 5/31/2011 385 402 0.9515 422 492 n 5 8/8/2011 200 400 600 800 1,000 1,200 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional)SITP, Psia I BHP, Psia Z BHP/Z, Psia CUM PROD, MMd LSMF Include? (Y/N) 1 2 3 10/6/2009 9/1/2010 10/11/2010 881 585, 595 923 612 622 0.8946 0.9276 0.9264 1,032 659 672 __ 0 282 293 Y Y Y 4 5/31/2011 385 402 0.9515 422 492 n 5 8/8/2011 433 452 0.9457 478 533 _ Y 6 10/31/2012 315 329 0.9602 342 631 Y 7 8/22/2013 385 402 0.9515 422 697 Y 8 6/12/2014 275 287 0.9651 297 721 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. FIELD: NICOLAI UNTY, STATE: KENAI P' RESERVOIR: L. Tsuga eF: 800 700 600 500 w IL a H 400 a x m R11 200 100 0 L 0 1,512 N 344.25 K UNIT #11 Ryder Scott Reservoir Solutions 5.0 (Public) (Protected) g±� K ULA BOR., ALASKA (WEST SIDE COOK INLET) =_ds 1349-1675') Upper Middle Completion if anv MMCF ♦ LSMF Data o Excluded Data • EUR = 686 ♦ OGIP = 740 100 200 300 400 500 600 700 800 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 9/13/2009 9/24/2009 583 677 603 0.9174 0.9259 7371 _ 651 0 _ 0 n Y 3 11/1/2012 315 325 0.9592 339 266 Y 4 8/22/2013 385 398 0.9504 _418 _ 322 _ y These results were prepared using Ryder Scott's teas Material Balance. This is not Ryder Scott work product. NICOLAI CREEK FIELD SOUTH Undesignated & BELUGA POOLS (SOUTH, WEST, & BELUGA PA's) - Aurora Gas, LLC N DATUM -1527' TVDSS #11 Beluga DATUM INITIAL – 663 psig -1704' TVDSS 8/2013 – 155 psig INITIAL -- 909 psig—� 8/2013 – 385 psia 7 SEC 30 SEC 29 NCU #11 ! DATUM -2285' TVDSS INITIAL – 1025 psig _ .-134F 8/2013 – 363 psig DATUM - -2766' TVDSS INITIAL – 959 prig (10/13) NCU 1A -228 i NCU SOUTH PA NCU 1 1 Tyonek DATUM DATUM -2537' fVDSS -2295' TVDSS INITIAL – 1211 psig N 2 INITIAL – 914 psig 8/2013 – 365 psig 4/2013– 368 psig NCU 4 NCU 6 - Aurora Gas, LLC