Critical Velocity/ Nodal Stability Gas Well Predictions
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1 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 European Conference Gas Well Deliquification September 2007 Critical Velocity/ Nodal Stability Gas Well Predictions By J F Lea, PLTech LLC Lynn Rowlan, Echometer Charlie Reed, Devon
2 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Liquid Loading
3 GAS WELL GRADIENT COMPOSED OF FRICTION AND GRAVITY (dp/dl) = (dp/dl)el + (dp/dl)f + (dp/dl)acc HOLDUP (LIQUID) BUILDS WITH TIME AND LOWER 3 PRODUCTION
4 4
5 Determine Liquid Loading from Critical Velocity Buoyant weight of droplet in gas Droplet in flowing gas Drag from flowing gas tending to lift the droplet 5
6 F Gravity = g g C πd ρ L G 6 ( ρ ) 3 F 1 2 Drag, UP = ρgcd Ad ( VG Vd ) 2gC Where g = gravitational constant = ft/s 2 g C = lbm-ft/lbf-s 2 d = droplet diameter r L = liquid density r G = gas density C D = drag coefficient A d = droplet projected cross-sectional area V G = gas velocity V d = droplet velocity 6
7 Coleman, et al., (Exxon) V C, water 1/ 4 ( P) 1/ (.0031 P) P = = (.0031 P) 1/ 4 ft / s V C, cond 1/ 4 ( P) 1/ (.0031 P) P = = (.0031P ) Turner et al., (with 20% adjustment) 1/ 4 ft / s V water ( P) 1/ (.0031P) C, =.321 ft / 5 2 ( ) 1/ 4 1/ P V C, cond = ft / 1/ European ( Gas.0031 Well PDeliquification ) s s 7
8 Sample of Turner s data: Mostly at Higher WHP s 8
9 9
10 Example: Using Turner, 2 3/8 s, 100 psi, read~320 Mscf/D Turner Unloading Rate for Well Producing Water Rate (Mcfd) /2 OD ID 3-1/ / / / Flowing Pressure (psi) 10
11 Other References Related to Critical Velocity or Rate Lea, J.F., Nickens, H.V., and Wells, M.: Gas Well De-Liquification, first edition, Elsevier Press, Cambridge, MA (2003). Turner, R.G., Hubbard, M.G., and Dukler, A.E.: Analysis and Prediction of Minimum Flow Rate for the Continuous Removal of Liquids from Gas Wells, J. Pet. Tech. (Nov.1969) Coleman, S.B., Clay, H.B., McCurdy, D.G., and Lee Norris, H. III: A New Look at Predicting Gas-Well Load Up, J. Pet. Tech. (March 1991) Veeken, K., Bakker, E., and Verbeek, P.: Evaluating Liquid Loading Field Data and Remedial Measures, presented at the 2003 Gas Well De-Watering Forum, Denver, CO, March 3-4. Li, M., Li, S.L., and Sun, L.T.: New View on Continuous-Removal Liquids from Gas Wells, paper SPE presented at the 2001 SPE Permian Basin Oil and Gas Recovery Conference, Midland, TX, May Nosseir, M.A., Darwich, T.A., Sayyouh, M.H., and El Sallaly, M.: A New Approach for Accurate Prediction of Loading in Gas Wells Under Different Flowing Conditions, paper SPE presented at the 1997 SPE Production Operations Symposium, Oklahoma City, OK, March Duggan, J.O.: Estimating Flow Rates Required to Keep Gas Wells Unloaded, J. Pet. Tech. (December 1961) Yamamoto, H. and Christiansen, R.L.: Enhancing Liquid Lift from Low Pressure Gas Reservoirs, paper SPE prepared for presentation at the 1999 SPE Rocky Mountain Regional Meeting, Gillette, WY, May Bizanti, M.S. and Moonesan, A.: How to Determine Minimum Flowrate for Liquids Removal, World Oil, (Sept. 1989) Ilobi, M.I. and Ikoku, C.U.: Minimum Gas Flow Rate for Continuous Liquid Removal in Gas Wells, paper SPE presented at the 1981 SPE of AIME Annual Fall Technical Conference and Exhibition, San Antonio, TX, Oct
12 Critical Rate: Summary Turner, Coleman and other models do not agree Critical gas rate independent of liquid rate Theoretically better to use at pressure downhole but seldom attempted Simple model Must be considered approximate but widely used with success 12
13 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Nodal Analysis
14 Nodal Analysis : A Model of the Well 14
15 Nodal Analysis (Schlumberger) Inflow to the node PR P (upstream components press drop s) = Pnode Outflow from the node Psep + P (downstream components press drop s) = Pnode Inflow Outflow Pressure Rate 15
16 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Inflow Curves
17 Inflow or Reservoir Curve Reservoir Inflow curve often represented by: Q = C ( Pr 2 Pwf 2 ) n. (back pressure equation) Inflow Pressure Rate 17
18 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Outflow Curves
19 Nodal Analysis (Schlumberger) At low rates, liquid builds up in the tubing and requires more pressure to flow Down-hole pressure Liquid Buildup Tubing J-Curve (Use various correlations, Gray, etc. ) Friction Rate 19
20 Liquid Loading Liquid loading occurs when gas rate is too low to efficiently remove the produced liquids Liquid Loading symptoms of unstable flow behavior and potential logging off of the well Tubing Curves PSIA S1 S2 S3 S1 S1 - Tubing Flow - Ptbg = 250 psig S2 - Tubing Flow - Ptbg = 250 psig S3 - Tubing Flow - Ptbg = 250 psig Cond Water.0 bbl/mmscf 29.6 bbl/mmscf S " at 3220 ft S2-3.5" at 3220 ft S3-4.5" at 3220 ft Gray Correlation Gas Rate (mscf/d) ISABEL A1 S2 S3 20
21 Nodal Analysis : Effects such as Size of the Tubing Diameter vs. Flow Rate can be studied 21
22 BIGGEST ERROR in Multiphase Flow Predictions Nodal Turn-Up Points 22
23 Liquid Loading J-Curve with Gray Flowing BHP (psig) Unstable flow High liquid buildup LIQUID LEVEL PRESENT IN WELL Tbg - Critical Rate (Min BHP) = 547 mscf/d Pfwh Cond Water 2.375" at ft Optimal Operation 125psig.0 bbl/mmscf 15.0bbl/MMscf Stable flow High friction May have some liquid buildup Gas Rate (mscf/d) Liquid loading occurs when gas rate is too low to efficiently remove the produced liquids This results in unstable flow behavior and potential logging off of the well Liquid Loading J-Curve with Tubing to Perfs 23
24 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Nodal Stability
25 Nodal Analysis : Stability Stability A B Flow around A & B is unstable Flow around C and D is stable Down-hole pressure C D Rate 25
26 Tubing crv, no flow Psi on perfs Inflow or rsvr curve Tubing crv, flow Tubing crv, more flow Intersections are flow pts Tubing crv, flow but unstable BPD Rate Increasing -> 26
27 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Model Gas Well
28 Example Gas Well Data: Reservoir: C = Mscf/D n = 1.0 Pr=1500 psi Tubing: 2 3/8 s to 10,000 Liquids: 50 bbl/mmscf Pressures/Temps/Fluid Properties Pwh: 100 psi Twh: 100 F BHT: 200 F GG:.7 50 bbl/mmscf WG: 1.03 WOR: 1. 28
29 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Example Output
30 Well flow unstable according to shape of outflow curve at point of intersection with IPR 30
31 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Effects of Tubing Size
32 Smaller tubing such as 1.61 or 1.38 (or smaller) ID stabilizes flow. Critical rate for 1.61 is 245 mscfd Critical rate for 1.38 is 152 mscfd So 1.61 or smaller stabilizes and flows above critical rate 32
33 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Effects of Surface Pressure
34 Adding constant surface pressure such as higher separator pressure does not stabilize or tend to flow above critical rate 34
35 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Effects of Restrictions at Bottom of Tubing
36 Adding a choke restriction at bottom hole of.15 diameter or.14 diameter stabilizes flow. It is still below critical flow however 36
37 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Effects of Restrictions at Surface
38 Adding a choke of.21 diameter or.18 diameter at surface stabilizes flow. It is still below critical rate however When the Slope of the Tubing Curve is up and to the left, then Gas Flow from the Well is stabilized and mist is lifting all liquids from the Well. When the Slope of the Tubing Curve is DOWN and to the left, then Gas Flow from the Well is unstable and liquid loading is occurring in the Well. 38
39 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Effects of Flowline
40 A flowline of more and more pressure drop has a stabilizing effect but flow is still below critical rate 40
41 Case History: Choke The well was drilled towards the end of 2005 and in the beginning of It is completed in the Cotton Valley and Travis Peak formations. The interval is over 3,000 Recently, we lost our stock tank on location to lighting and we had to have our production pushed to the tank battery, a much further distance away. The well was not strong enough to flow against the back pressure from the longer line and the well died. Strangely enough, we found once we shut the well in and brought it back on with a slight choke the production became more stable. We have seen that on some other wells once the production has fallen below the critical rate. The choke seems to flatten the production curve rather then having to shut the well in and flowing intermittently. 41
42 Well With Choke Added 42
43 Choke: Summary: Choke on well above critical just reduces rate Choke on artificially lifted well adds HP or reduces rate except for special cases May be window on wells that are loaded (and maybe best on wells intermitting) that seems to allow wells to once again flow continuously instead of having to intermit. 43
44 Originally Presented at: Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5-7, 2007 Summary & Conclusions
45 Summary & Conclusions Smaller tubing has stabilizing effect but if too small will add too much friction (well known) Adding constant pressure to the surface of the well reduces rate and does not stabilize the well or tend to flow below critical Adding lower constant pressure to the surface of the well stabilizes the well and tends to flow above critical rate (compression) 45
46 Summary & Conclusions Continued The effects of a flowline (rate dependent pressure drop) has a stabilizing effect on the flow but flow continues below critical if below to start with as FL pressure drop is added. Adding too much of a rate dependent pressure drop will (choke) can reduce flowrate to zero Adding a rate dependent pressure drop (choke) to a loaded well has a stabilizing effect but well remains flowing below critical rate 46
47 Possible Uses of Analysis If a well is loaded and it must be intermitted to continue production, consider using a choke to get the well to flow continuously once again. The cost is low to try this. DO NOT add chokes across the field indiscriminately or you will have problems. Thanks to Mohan Kelkar, Tulsa University, for pointing out the stabilizing effects of adding chokes to loaded gas wells. At least stabilizing as far as Nodal Analysis predictions are concerned. 47
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